OMNIPOWER® direct and CT meters - ANSAC Technology...K am st rup A/S• 5 1 2-3 _GB H 07 ZL O ig...

OMNIPOWER® direct andCT meters

Technical description

2/104Kamstrup A/S • 5512-1235_GB_H1_07-2020_AZL_Original version

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Contents1 ...................................................................................................................... 8Revision history

2 ...................................................................................................................... 10Introduction to OMNIPOWER®

3 ...................................................................................................................... 11Technical specification

................................................................................................................ 113.1 Electrical specifications

............................................................................................................... 113.1.1 Technical data for OMNIPOWER® direct meters

............................................................................................................... 123.1.2 Technical data for OMNIPOWER® CT meters

................................................................................................................ 133.2 Mechanical specifications

................................................................................................................ 153.3 Type number overview

................................................................................................................ 163.4 Approvals

................................................................................................................ 163.5 Connection diagrams

................................................................................................................ 193.6 Terminal numbering

4 ...................................................................................................................... 21How to use OMNIPOWER®

................................................................................................................ 214.1 Installation and power-up

................................................................................................................ 214.2 Power-up/start-up sequence

................................................................................................................ 224.3 Display functions

................................................................................................................ 234.4 Push button functionalities

................................................................................................................ 244.5 Tamper

................................................................................................................ 244.6 Meter logger events

............................................................................................................... 244.6.1 Meter status logger (1.1.99.98.2.255)

................................................................................................................ 244.7 Time management

............................................................................................................... 244.7.1 Backup

............................................................................................................... 254.7.2 Hour counters

............................................................................................................... 254.7.3 Calendar and daylight-saving time plan

......................................................................................................... 254.7.3.1 Daylight saving time logger behavior

............................................................................................................... 254.7.4 RTC setting and adjustment using push button

............................................................................................................... 254.7.5 RTC adjustment logger (1.1.99.98.3.255)

................................................................................................................ 264.8 Power and energy measurements

............................................................................................................... 264.8.1 Limitations for OMNIPOWER® three-phase, three-wire (Aron) CT and

direct meters............................................................................................................... 274.8.2 Power measurements

............................................................................................................... 284.8.3 Energy registration


............................................................................................................... 304.8.4 Calculation methods of an OMNIPOWER® three-phase meter

............................................................................................................... 324.8.5 Mean power values

............................................................................................................... 334.8.6 Peak power values

............................................................................................................... 334.8.7 Energy tariff/TOU registers

......................................................................................................... 344.8.7.1 Hardware-controlled – 230 VAC input

......................................................................................................... 344.8.7.2 On-demand – system-controlled

......................................................................................................... 344.8.7.3 Internal tariff plan in the meter

................................................................................................................ 354.9 Data loggers

............................................................................................................... 354.9.1 Load profile logger (1.1.99.1.0.255)

............................................................................................................... 364.9.2 Monthly debiting logger (1.1.98.1.0.255) (2)

............................................................................................................... 384.9.3 Daily/weekly/monthly debiting logger (1.1.98.2.0.255)

............................................................................................................... 394.9.4 Daily Logger (1.1.98.128.0.255)

............................................................................................................... 414.9.5 Analysis logger (1.1.99.1.1.255)

................................................................................................................ 464.10 Meter readout

............................................................................................................... 464.10.1 Manual display readout

............................................................................................................... 474.10.2 9-digit value field

............................................................................................................... 474.10.3 Unit field

............................................................................................................... 474.10.4 Object identification field

............................................................................................................... 474.10.5 Quadrant reading

............................................................................................................... 474.10.6 Text field

............................................................................................................... 484.10.7 Module indication

............................................................................................................... 484.10.8 Error symbol

............................................................................................................... 484.10.9 Breaker symbol

............................................................................................................... 484.10.10 Tamper symbol

............................................................................................................... 484.10.11 Radio network symbol

............................................................................................................... 484.10.12 Prepayment symbol

............................................................................................................... 484.10.13 Tariff/TOU indication

............................................................................................................... 494.10.14 Mains voltage reading

............................................................................................................... 494.10.15 Phase current indication

............................................................................................................... 494.10.16 Phase sequence indication

............................................................................................................... 504.10.17 Protocols

......................................................................................................... 504.10.17.1 Kamstrup Meter Protocol (KMP)

......................................................................................................... 504.10.17.2 DLMS

......................................................................................................... 504.10.17.3 1107


............................................................................................................... 504.10.18 Local readout via optical interface – METERTOOL OMNIPOWER®

............................................................................................................... 504.10.19 Integrated OMNICON® radio mesh connectivity

............................................................................................................... 514.10.20 Integrated OMNICON® point-to-point connectivity

............................................................................................................... 514.10.21 Full encryption on all interfaces

............................................................................................................... 514.10.22 M-Bus and RS-485 connectivity

................................................................................................................ 524.11 Modularity options

............................................................................................................... 524.11.1 Primary modules

............................................................................................................... 524.11.2 CCC modules

................................................................................................................ 534.12 Disconnect functionality

............................................................................................................... 544.12.1 Disconnect function

............................................................................................................... 544.12.2 Manual disconnection and reconnection

............................................................................................................... 554.12.3 Remote disconnection from a smart metering system

............................................................................................................... 554.12.4 Smart disconnect

............................................................................................................... 554.12.5 Disconnection basis

............................................................................................................... 564.12.6 Current-controlled disconnection

............................................................................................................... 564.12.7 Power-controlled disconnection

............................................................................................................... 564.12.8 Overvoltage disconnection

............................................................................................................... 574.12.9 Delayed disconnection

............................................................................................................... 584.12.10 Reconnection

............................................................................................................... 594.12.11 Disconnection on meters with APS

............................................................................................................... 594.12.12 Event logger for disconnect/connect history (1.1.99.98.5.255)

............................................................................................................... 594.12.13 Prepayment

............................................................................................................... 594.12.14 Prepayment principle

................................................................................................................ 614.13 Power quality measurements

............................................................................................................... 614.13.1 Frequency measurements

............................................................................................................... 614.13.2 Voltage variations

......................................................................................................... 624.13.2.1 Long-term deviations

......................................................................................................... 624.13.2.2 Short-term deviations

............................................................................................................... 634.13.3 Voltage outage

............................................................................................................... 644.13.4 Configuration of voltage quality measurements

......................................................................................................... 654.13.4.1 Voltage sags and swells with a duration 100 ms – 1 second

............................................................................................................... 654.13.5 Rapid voltage change

............................................................................................................... 664.13.6 Supply voltage unbalance

............................................................................................................... 664.13.7 Total harmonic distortion (THD)


............................................................................................................... 664.13.8 Readout of the power quality measurements

......................................................................................................... 664.13.8.1 Voltage quality logger (1.1.99.98.16.255)

......................................................................................................... 684.13.8.2 Occurrence counter logger (1.1.99.98.17.255)

............................................................................................................... 694.13.9 Power factor

............................................................................................................... 694.13.10 Neutral fault detection

......................................................................................................... 724.13.10.1 Neutral fault logger (1.1.99.98.12.255)

............................................................................................................... 724.13.11 Earth fault detection

......................................................................................................... 734.13.11.1 Earth fault detction logger (1.1.99.98.19.255)

................................................................................................................ 744.14 Other smart grid functionalities

............................................................................................................... 744.14.1 Firmware upload

............................................................................................................... 744.14.2 Alarm handling/push alarms

............................................................................................................... 744.14.3 All phase power outage alarm ("last gasp")

............................................................................................................... 754.14.4 Control of external load relays

............................................................................................................... 754.14.5 Multi-utility options

............................................................................................................... 764.14.6 Miscellaneous use

............................................................................................................... 764.14.7 Pulse inputs in the module area

......................................................................................................... 774.14.7.1 Example of pulse input from a water meter

......................................................................................................... 774.14.7.2 Example of pulse input from an electricity meter

............................................................................................................... 784.14.8 Pulse outputs in module area

............................................................................................................... 784.14.9 S0 output

............................................................................................................... 794.14.10 Auxiliary power supply (APS)

5 ...................................................................................................................... 81Ordering specification

................................................................................................................ 815.1 Meter configuration

................................................................................................................ 815.2 Hardware configuration

................................................................................................................ 845.3 Software configuration

................................................................................................................ 905.4 Display configuration

................................................................................................................ 985.5 Tariff control configuration

................................................................................................................ 985.6 Load control configuration

................................................................................................................ 985.7 Smart disconnect setup

................................................................................................................ 985.8 Sealable push button configuration

................................................................................................................ 995.9 1107 protocol configuration

................................................................................................................ 995.10 Customer labels

................................................................................................................ 1005.11 Sealing

................................................................................................................ 1015.12 Packing


............................................................................................................... 1025.12.1 Box solution

............................................................................................................... 1025.12.2 Pallet solution

................................................................................................................ 1035.13 Accessories


1 Revision history______________________________________________________________

Rev. Description Meter software revision

A1 First release of this technical description for OMNIPOWER®

direct meters. Does not include OMNIPOWER® CT meters.

OMNIPOWER® direct meters:

· SW no.: 5098736, rev. B1 > P1

A2 Update of the power quality measurements section. OMNIPOWER® direct meters:

· SW no.: 5098736, rev. B1 > P1

A3 Includes OMNIPOWER® ST variant (symmetric terminals)

meters.

OMNIPOWER® direct meter:

· SW no.: 5098736, rev. P1 > P1

B1 Includes OMNIPOWER® CT meters. OMNIPOWER® direct meters:

· SW no.: 5098736, rev. Q1

OMNIPOWER® CT meters:

· SW no.: 50981040, rev. Q1

C1 Includes new overvoltage disconnect functionality. OMNIPOWER® direct meters:

· SW no.: 5098736, rev. R1, S1, T1,

U1


· SW no.: 0981040, rev. R1, S1, T1,

U1

D1 Includes new OMNIPOWER® variant with last gasp and

encryption.


· SW no.: 5098736, rev. R1, S1, T1,

U1

· SW no.: 50981173 rev. D1, E1 (No

DLMS)

· SW no.: 0981165 rev. D1 (No

DLMS)


· SW no.: 50981040, rev. R1, S1, T1,

U1

E1 Updates:

· New registers for analysis logger.

· New register for voltage quality (VQ1) logger.

· Introduction of daily logger (only for 50981173, 50981165).


SW no.: 5098736, No updates

SW no.: 50981173 rev. F1, G1, K1

SW no.: 50981165 rev. F1, L1


SW no.: 50981040, rev. R1, S1, T1,

U1

F1 Updates:

· OMNIPOWER® three-phase DIN rail meter.

· Interpretation of voltages for three-phase, three-wire meters

(Aron).

· Description of earth fault detection and earth fault logger.

· Limitations for Aron meters according to current and power

values.


SW no.: 5098736, No updates

SW no.: 50981173 rev. > AB1

SW no.: 50981165 rev. > AB1


SW no.: 50981040, rev. > S1


Rev. Description Meter software revision

G1 Updates:

· Detailed description of earth fault detection and event

logging.

· Description of 8-channel load profile logging.


SW no.: 5098736, rev. > X2

SW no.: 50981173 rev. > AE6

SW no.: 50981165 rev. > AE6


SW no.: 50981040, rev. > X2

SW no.: 50981251, rev. > V6

H1 Updates:

· Added "Use dayligt saving time as midnight logger trigger "section.

· Updated "Monthly debiting logger " section with newlysupported registers.

· Updated "Daily logger " section with newly supportedregisters.

· Updated "Daily/weekly/monthly debiting logger " sectionwith newly supported registers.

· Added description of behavior for maximum/minimumregisters and associated RTC values for Monthly debitinglogger , Daily logger and Analysis logger .


SW no.: 50981173 rev. AF1

SW no.: 50981165 rev. AF1


SW no.: 50981251, rev. W1

25

36

39

38

36 39 41


2 Introduction to OMNIPOWER®______________________________________________________________OMNIPOWER® is a smart electricity meter prepared for the future demands required by smart grid

implementations. It provides a detailed insight into consumption patterns at the low-voltage part of

the power grid. It is also a grid sensor for collection of relevant power quality information.

OMNIPOWER® offers a list of features, for example:

· Optimized functionalities for smart metering systems

· Communication for smart home applications

· Security against tampering

· Ultra-low power consumption

· Remote firmware update (approved according to WELMEC 7.2).

From the factory, the meter can be configured to measure both imported and exported energy. The

measurements are saved in a permanent memory. As default, OMNIPOWER® can generate load

profiles in all four quadrants. A load profile provides detailed information about consumed and

produced energy. An additional logger with 16 channels contains data for analysis purposes.

Part of OMNIA® OMNIPOWER® with integrated OMNICON® radio communication is an essential part of the

OMNIA® all-comprising smart grid platform shown in the figure below. OMNIA® offers a full line of

smart technology, support and knowledge.

OMNIA® overview

As part of OMNIA®, OMNIPOWER® can be used as the gateway for collecting other consumption

types such as water, gas, heating and cooling. It is also prepared for Home Area Network (HAN)

communication via a Consumer Communication Channel (CCC) module which can be inserted on

the meter front by the consumer.


3 Technical specification______________________________________________________________This chapter describes the technical specifications for OMNIPOWER®.

OMNIPOWER® provides a range of technical and mechanical features with high performance and

reliability. The following technical specifications are both valid for OMNIPOWER® direct and CT

meters.

3.1 Electrical specifications

OMNIPOWER® is constructed with independent and galvanically separated measuring systems

(the number of measuring systems depends on the meter type). This ensures a correct

measurement irrespective of how many and which measurement systems are used.

A switch mode supply feeds the measuring circuits and main processor with voltage. Furthermore,

the switch mode supply functions as an excellent transient protection (in combination with varistors

and power resistors).

The use of shunt and switch mode supply also ensures that OMNIPOWER® direct meters are

immune to magnetic influence. Measured and calculated data is safely stored in an integrated non-

volatile memory (EEPROM).

Technical data

Nominal frequency, fn 50 or 60 Hz ± 5 %

Phase displacement Unlimited

Data storage EEPROM; > 10 years without voltage.

Display LCD, 7 mm digit height (value field).

LCD, 5 mm digit height (identification readings).

LCD, 3 mm digit height (voltage readings).

Real-time clock (RTC) accuracy Typically 5 ppm at 23°C.

Backup battery lifetime > 10 years at normal operation.

Supercap lifetime > 10 years at normal operation.

Supercap backup time 5 days at fully charged.

3.1.1 Technical data for OMNIPOWER® direct meters

Technical data

Measuring principle:

Current:

Voltage:

One-phase current measurement via current shunt.

One-phase voltage measurement via voltage divider.

Nominal voltage, Un 3x230 VAC -20 % - +15 % (for Aron meter only)

1x230 VAC -20 % - +15 %

2x230/400 VAC -20 % - +15 %

3x230/400 VAC -20 % - +15 %


Technical data

Current, Itr - Ib (Imax) OMNIPOWER® three-phase and single-phase meter

Without breaker With breaker

0.25-5(60)A 0.25-5(60)A

0.25-5(80)A 0.25-5(80)A

0.25-5(100)A 0.25-5(100)A

Accuracy class,

Active energy

Reactive energy

MID: Class A, Class B

IEC: Class 2, Class 1

IEC: Class 3, Class 2

Own consumption (per phase)* OMNIPOWER® three-phase Without breaker With breaker

Current circuit 0.01 VA 0.01 VA

Voltage circuit 0.4 VA

0.1 W

0.4 VA

0.1 W

OMNIPOWER® single-phase Without breaker With breaker

Current circuit 0.01 VA 0.01 VA


0.2 W

0.6 VA

0.2 W

Meter constant 1000 imp/kWh

S0 pulse diode 1000 imp/kWh, kvarh

Pulse time 30 ms ± 10 %

S0 pulse output

(Not on DIN rail meter)

1000 imp/kWh


* Measured on phase L1 according to MID type approval

3.1.2 Technical data for OMNIPOWER® CT meters

Technical data

Measuring principle:

Current:

Voltage:

One-phase current measurement via current transformers.

One-phase voltage measurement via voltage divider.

Nominal voltage, Un 3x230 VAC -20 % - +15 % (for Aron meter only)

3x230/400 VAC -20 % - +15 %

Current, Imin - In (Imax) OMNIPOWER® CT meter

0.01-1(6)A

0.05-5(6)A

Accuracy class,

Active energy

Reactive energy

MID: Class B, Class C

IEC: Class 1, Class 0.5

IEC: Class 2

Own consumption (per phase)* OMNIPOWER® CT meter

Current circuit 0.02 VA


Technical data


0.1 W

Meter constant 10000 imp/kWh

S0 pulse diode 10000 imp/kWh, kvarh


S0 pulse output 5000 imp/kWh


* Measured on phase L1 according to MID type approval

3.2 Mechanical specifications

OMNIPOWER® is designed as a two-piece plastic construction, consisting of housing and meter

cover, both made of fire resistant plastic. The housing is constructed in such a way that it protects

the metrological functions. It is not possible to open the housing without breaking the metrological

seal.

Technical data

Operating temperature -40°C - +70°C

-40°C - +55°C (DIN rail meter)

Storage temperature -40 °C - +85 °C

Protection class IP54

IP 51 DIN rail meter

Protection class II

Relative humidity < 75 % year’s average at 21 °C

< 95 % less than 30 days/year at 25 °C

Weight OMNIPOWER® Without breaker With breaker

Single-phase meter 550g 700g

Single-phase meter (ST) 550g 700g

Three-phase meter 900g 1100g

Three-phase DIN rail 1000g

CT meter 900g NA

Application area Indoor or outdoor in suitable meter cabinet

Materials Glass reinforced polycarbonate

DimensionsThe dimensions of OMNIPOWER® can be seen in the figures below.


OMNIPOWER® CT and three-phase meter

Dimensional sketch of OMNIPOWER® CT and three-phase meter with/without breaker

OMNIPOWER® single-phase OMNIPOWER® single-phase ST-meter

Dimensional sketch of OMNIPOWER® single-phase meter with/without breaker

The meter cover can be ordered with different lengths. A short version allows pre-mounted

terminal pins or wires to be mounted, while the longer version covers the terminal inputs and

outputs.


OMNIPOWER® three-phase DIN rail

Dimensional sketch of OMNIPOWER® three-phase DIN rail meter with breaker

3.3 Type number overview

OMNIPOWER® is available with a range of optional hardware features depending on the

application for which it is used. The meter can, for example, be delivered with an internal

disconnect function for disconnection and connection of the consumer’s supply, configured for the

measurement of energy in all four quadrants, with integrated radio transceiver and auxiliary power

supply (APS). The choice between these options defines the meter type number.

The OMNIPOWER® type numbers consist of 18 characters that describe the configuration of the

meter regarding hardware and mechanical options. The type numbers for the different

OMNIPOWER® meters have the following structure:

OMNIPOWER® meter Type Type number

OMNIPOWER® three-phase

meter

Three-phase, four-wire meter 684-1X-3XX-NxX-XXXX-XXX.


meter

Three-phase, three-wire meter

(Aron)

684-1X-2XX-NxX-XXXX-XXX.


DIN rail meter

Three-phase, four-wire meter 684-14-39X-NxX-XXXX-XXX.

OMNIPOWER® single-phase

meter

Single-phase, two-wire meter 686-1X-1XX-NxX-XXXX-XXX.

OMNIPOWER® CT meter Three-phase, four-wire meter 685-11-3XX-DxX-0X11-XXX.

OMNIPOWER® CT meter Three-phase, three-wire meter

(Aron)

685-11-2XX-DxX-0X11-XXX.

For the complete configuration of the OMNIPOWER® type number, please see "Ordering

specification ". 81


3.4 Approvals

OMNIPOWER® is type approved according to the Measuring Instruments Directive (MID) for active

positive energy and according to the national requirements for other energy types, where required.

Type approval Norm

Active energy EN 50470-1

EN 50470-3

Reactive energy and active energy IEC 62052-11

IEC 62053-21

IEC 62053-22

IEC 62053-23

Various Norm

Terminal DIN 43857

BS 7856

S0 pulse output DIN 43864

(DIN rail meter does not have S0)

Optical reading EN 62056-21 mode C

OBIS codes IEC 62056-61

Breaker EN 62055-31, Annex C

3.5 Connection diagrams

The valid connection diagram appears from the type label on the front of the meter and can be

seen below.

OMNIPOWER® three-phase, four-wire (S0)


OMNIPOWER® three-phase, four-wire (APS version)

OMNIPOWER® three-phase, three-wire (Aron)

OMNIPOWER® three-phase DIN rail meter, four-wire


OMNIPOWER® single-phase, two-wire

OMNIPOWER® single-phase, two-wire – symmetric terminals – ST-meter

OMNIPOWER® CT three-phase, four-wire


OMNIPOWER® CT three-phase, three-wire (Aron)

Connect the meter in accordance with the installation diagram on the type label of the meter.

3.6 Terminal numbering

Terminal numbering for OMNIPOWER® three-phase meter with S0 or APS

Terminal numbering for OMNIPOWER® three-phase meter with S0


Terminal numbering for OMNIPOWER® single-phase meter with S0

Terminal numbering for OMNIPOWER® single-phase ST-meter with S0

Terminal numbering for OMNIPOWER® CT-meter

Terminal numbering for OMNIPOWER® three-phase DIN rail meter


4 How to use OMNIPOWER®______________________________________________________________This chapter describes the use of OMNIPOWER® in details, the features implemented and the

benefits which the meter provides to the users.

4.1 Installation and power-up

It is essential that OMNIPOWER® is installed and connected as described in the installation

guides

For the connection diagrams of the specific meter types, please see the previous sections.

4.2 Power-up/start-up sequence

The display power-up sequence is shown below.

In the first five seconds after powering OMNIPOWER®, the ROM checksum is displayed with its

corresponding OBIS code.

In the next five seconds, the software type number and revision number of the meter is shown. The

value field describes the software number while the software revision is shown in the text field in

the upper right corner of the display.

The phase indicators L1, L2 and L3 show whether voltage is applied to each phase. The arrows

indicate any direction of the power flow for each phase. The phase sequence is also indicated. The

sequence is defined in the table below.


Symbol Phase sequence

L1-L2-L3

L1-L3-L2

After additional 5 seconds, the meter starts operational mode and begins displaying its automatic

display list.

If the meter is part of OMNIA® Suite, the integrated radio module starts searching for a network.

This is indicated by a flashing antenna symbol. When a network is located, and the meter is in

contact and recognized by a concentrator, the antenna symbol will be constantly “On”.

It is possible to delay the start-up of the integrated radio for 5 minutes, if the left push button is

pushed for approximately 5 seconds immediately after power is applied to the meter. The RF

symbol will turn off to indicate that the start-up is delayed.

The radio will automatically start searching for a radio network when the 5 minutes are passed, or

immediately after a re-power of the meter.

4.3 Display functions

OMNIPOWER® provides the possibility of up to four display lists to which a number of meter

values/parameters can be attached. The table below gives an overview of the available display

lists.

Display view Description Shifting Maximum

values

Automatic display list A list of registers that is shown automatically

in the display.

Automatically

10 seconds

(fixed)

16

Manual consumer display listA list of registers that can be seen by pushing

the left push button on the meter front.

Manually

via left push

button

30

Manual utility display list As manual consumer display list, but this list

can only be seen by pushing the sealable push

button.

Manually

via right push

button

16

Supply backup display list In case the meter is disconnected from the

main supply, this display list still allows the

user to read out a number of meter values. The

display is only activated by pushing the left

push button.

Manually

via left push

button

8

Available display lists in OMNIPOWER®

Each list can be customized at ordering, and can also be reconfigured after installation. OMNIA®

also provides the possibility to update the display lists remotely.


4.4 Push button functionalities

Two push buttons are available on the front of OMNIPOWER® as shown in the figure below.

OMNIPOWER® push buttons

The left push button is used for manual display scrolling and manual connect/disconnect of internal

breakers if the meter is configured for this.

The right push button is sealable, and the following functionalities can be enabled via configuration:

· Set time and date

· Adjust time

· Execute debiting stop

· Disable/enable optical port

· Change meter number

· Set tariff plan and load control plan

· Test load control relays.Each function can be enabled independently in the setup. Configuration of the sealable push buttonmust be done at the time of ordering the meter.

The right push button can only be activated when the slot is in a vertical position. The button can be

locked by turning it 90° to horizontal position; in this position a sealing can be mounted to lock the

push button.

Release of sealable push button


4.5 Tamper

OMNIPOWER® has registration of magnetic field detection and meter cover tampering. Any

registration can be accompanied by indication in the display. This indication can be configurable to

be temporary (i.e. it disappears when the source to tamper disappears), or permanently until a

tamper release command is received either from a smart metering system or by activating the

sealable push button.

With OMNIPOWER® meters implemented in OMNIA®, it is also possible to receive tamper

registrations as push alarms to the meter data management (MDM) system.

4.6 Meter logger events

The following sections describe the complete lists of events that are detected in the

OMNIPOWER® meter, and in which loggers the different events are registered.

4.6.1 Meter status logger (1.1.99.98.2.255)

OMNIPOWER® has a status logger which contains information about the status events of the

meter. A registration in the logger can be triggered by the following events:

· EEPROM access failure

· ROM checksum fail

· Tamper detection

· Magnetic field detection

· Meter reset

The meter status logger is circular and will therefore contain the 200 newest meter status events.

4.7 Time management

OMNIPOWER® has an integrated real-time clock (RTC) to provide measured data with an

accurate time stamp (typically 5 ppm at 23 °C). The RTC is used to generate time stamps on load

profile values and event registrations and to keep any tariff and load control plans on track.

4.7.1 Backup

In case of power supply outage, the RTC function is supplied by either a battery or rechargeable

backup unit (supercap). The backup time depends on the period of time that the meter is without

mains supply. In addition, the backup gives access to further functions such as display views

despite the lack of mains supply.

The lifetime of the backup unit also depends on the mains voltage supply to the meter and the

ambient temperature.


4.7.2 Hour counters

As the RTC manages the date and time in the meter, an hour counter register manages the

number of operating hours of the meter, i.e. the number of hours where main voltage are supplied

to the meter.

As a supplement to the total hour counter, the meter also contains separate counters for all eight

tariffs available in the meter.

4.7.3 Calendar and daylight-saving time plan

It is possible to set up a calendar plan useable for tariff and load control. The calendar plan can

contain up to four different seasons, and each season can have different weekly plans. For details

about how a weekly plan is divided into working days, non-working days and holidays, please see

“Internal tariff plan in the meter ”.

In addition to the “regular” calendar plan, a list of exceptions days can be added to the calendar.

The list can contain up to 200 days 20 years ahead in time. Exceptions days will have the same

tariff plan as holidays.

Finally, OMNIPOWER® also has an option for a daylight saving time plan which can be

programmed in the meter with corresponding configuration of start and end dates for up to 20

years ahead in time. However, all time stamps in data loggers and event loggers are done in

normal time and does not take any daylight light saving time into account.

4.7.3.1 Daylight saving time logger behavior

The OMNIPOWER® RTC can be configured to follow a defined daylight saving time plan, if the

daylight saving time register (1.1.96.52.11.255) is enabled. Enabling of a daylight saving time plan

will not change the behavior of any logger, i.e. midnight loggers will continue to do log entries at

00:00 normal time all year. If, however, the register

"UseDstAsDailyLoggerTrigger" (1.1.96.52.12.255) is also enabled (i.e. set to "1"), midnight loggers

will change behavior and do log entries at 23:00 normal time (00:00 local time) in the defined

daylight saving period.

Note Time stamps in data loggers are always in normal time.

4.7.4 RTC setting and adjustment using push button

It is possible to configure OMNIPOWER® to enable RTC setting/adjustment using the right push

button.

4.7.5 RTC adjustment logger (1.1.99.98.3.255)

The time is adjustable via the configuration program METERTOOL OMNIPOWER® or via a smart

metering system like OMNIA®. Changes are registered in a dedicated RTC adjustment logger, and

34


if needed, the registration can be filtered to avoid insignificant adjustments, e.g. less than 7

seconds, to fill the log.

4.8 Power and energy measurements

Energy consumption is calculated as an expression of the phase current, the phase voltage and

time. The energy registration per measuring system is communicated to the legal processor of the

meter via the internal bus system of the meter; and is accumulated in the main registers of the

meter.

4.8.1 Limitations for OMNIPOWER® three-phase, three-wire (Aron) CT and direct meters

In "Power and energy measurements " and "Data loggers ", the information is valid for all

meter types and variants, with a few exceptions for OMNIPOWER® three-phase three-wire (Aron)

CT and direct meters.

The CT meter type only has two available measuring systems as shown in "Connection

diagrams ". Therefore, it does not measure the current in phase L2 and the value will always be

“0” in case this register is read out or used in any data logger. Instead, the current in L2 is

measured either by the system in L1 or the system in L3. The same counts for power registers (P,

Q and S). The total power consumption is split accordingly to the two measuring systems in L1

and L3, respectively.

The direct meter type also has two measuring systems for energy registration. However, due to

the implementation of earth fault detection, the current in L2 is measured and the value is available

for readout or in the data loggers. The power registration is, like for CT meters, measured by the

systems in L1 and L3 and the phase values for P, Q and S, and is therefore ”0” for L2.

26 35

16


4.8.2 Power measurements

OMNIPOWER® is constructed as a four-quadrant meter, which means active, reactive and

apparent power and energy measurements in the flow directions shown in the figure below.

Energy and power measurement in four quadrants

All power values in OMNIPOWER® are measured in kW (P), kvar (Q) and KVA (S), and are

available for readout or in data loggers with three decimals.

The available power registers in OMNIPOWER® are listed in the table below with the

corresponding OBIS codes according to EN 62056-61.


Designation Quadrant

illustration

Description Unit Display

OBIS code

P+

P14

The active positive power consists of active power from

quadrants 1 and 4.

kW 1.7.0

P-

P23

The active negative power consists of active power from

quadrants 2 and 3.

kW 2.7.0

Q+

Q12

The reactive positive power consists of positive inductive

power from quadrant 1 and positive capacitive power from

quadrant 2.

kvar 3.7.0

Q-

Q34

The reactive negative power consists of negative inductive

power from quadrant 3 and negative capacitive power from

quadrant 4.

kvar 4.7.0

S+

S14

The positive apparent power from quadrant 1 and 4. kVA 9.7.0

S-

S23

The negative apparent power from quadrant 2 and 3. kVA 10.7.0

Main power registers in OMNIPOWER®

All the values in the table are instantaneous values with an update frequency of 1 Hz. In addition to

these instantaneous power registers, OMNIPOWER® also contains a range of derived power

registers, e.g. mean values and peak values. These different values are described in "Mean power

values " and "Peak power values ".

4.8.3 Energy registration

OMNIPOWER® is available as an import/export meter for active, reactive and apparent energy.

The possible energy registers are described in the table below with the corresponding OBIS code

according to EN 62056-61.

Designatio

n

Quadrant

illustration


OBIS code*

A+

A14

The active positive energy consists of active energy

from quadrants 1 and 4.

kWh 1.8.0

1.8.x (tariff)

A-

A23

The active negative energy consists of active energy

from quadrants 2 and 3.

kWh 2.8.0

2.8.x (tariff)

R+

R12

The reactive positive energy consists of positive

inductive energy from quadrant 1 and positive

capacitive energy from quadrant 2.

kvarh 3.8.0

3.8.x (tariff)

R-

R34

The reactive negative energy consists of negative

inductive energy from quadrant 3 and negative

capacitive energy from quadrant 4.

kvarh 4.8.0

4.8.x (tariff)

R1

R+i

The positive inductive energy from quadrant 1. kvarh 5.8.0

32 33


Designatio

n

Quadrant

illustration


OBIS code*

R2

R+c

The positive capacitive energy from quadrant 2. kvarh 6.8.0

R3

R-i

The negative inductive energy from quadrant 3. kvarh 7.8.0

R4

R-c

The negative capacitive energy from quadrant 4. kvarh 8.8.0

E+

E14

The positive apparent energy from quadrant 1 and 4. kVAh 9.8.0

9.8.x (tariff)

E-

E23

The negative apparent energy from quadrant 2 and 3. kVAh 10.8.0

10.8.x (tariff)

* The x indicates the corresponding tarif f for the energy type.

Main energy registers in OMNIPOWER®

Some of the energy registers in the table are used as the legal energy registration in

OMNIPOWER®. Configuration of the meter decides which energy registers to be legal.

The legal energy registers are automatically used as values for the load profile data logger, which

is described in detail in “Load profile logger ".

In addition to energy registers, a number of deviated energy registers are also available in the

meter. These are listed in the table below.

For OMNIPOWER® CT meters, the registers 1.8.x, 2.8.x, 3.8.x, 4.8.x, 5.8.0 and 8.8.0 are available

as both secondary and primary values. The secondary values can be configured for use in display

and load profile logger.

Designation Description Unit Display

OBIS code

A1234 A register that sums the active positive and negative energy

numerically. Can be used as a control register for a one-way (A+)

meter.

kWh 1.15.8

A+ trip A resettable trip counter that accumulates total active positive energy

and resets via left push button (6 sec).

kWh 1.1.128

A- trip A resettable trip counter that accumulates total active positive energy


kWh 2.1.128

R+ trip A resettable trip counter that accumulates total active positive energy


kvarh 3.1.128

R- trip A resettable trip counter that accumulates total active positive energy


kvarh 4.1.128

E+ trip A resettable trip counter that accumulates total apparent positive

energy and resets via left push button (6 sec).

kVAh 9.1.128

35



OBIS code

E- trip A resettable trip counter that accumulates total apparent negative

energy and resets via left push button (6 sec).

kVAh 10.1.128

A-net

= |A+|-|A-|

A net calculation register that counts backwards if |A-| > |A+|. The

register is useable as informative register in the display, for

installations with microgeneration, e.g. solar cells. The register is not

available as a legal register in the load profile logger.

kWh 1.16.8

A*prepayment A prepayment register that counts down the kWh value which is

preset in the register. Used to disconnect the internal breaker when it

reaches zero.

kWh 0.130.0

A*prepayment,c

redit

Used as a credit register in case the exception time is active in the

prepayment functionality. Can only be reset by adding kWhs to the

meter.

kWh 0.130.1

* The register is not available in OMNIPOWER® CT meters.

Additional energy registers in OMNIPOWER®

The resolution by which all the energy readings are shown in the display can be set to the

following:

Display resolution Single-phase and

three-phase meters

CT meters

6.1 (000000.0) kWh/kvarh ü -

6.3 (000000.000) kWh/kvarh ü -

7.0 (0000000) kWh/kvarh ü ü

7.1 (0000000.0) kWh/kvarh - ü

7.2 (0000000.00) kWh/kvarh ü ü

Resolution for energy registers in OMNIPOWER®

Furthermore, it is possible to select or deselect leading zeroes. The configuration of the display

resolution and leading zeros are done when ordering the meter and cannot be reconfigured

afterwards due to legal requirements.

All secondary energy registers in OMNIPOWER® CT are shown with the display relosution 5.2

(00000.00) kWh/kvarh.

4.8.4 Calculation methods of an OMNIPOWER® three-phase meter

OMNIPOWER® provides three methods for calculating the energy in three-phase meters. Three

similar meters can therefore obtain different results for energy measurement depending on the

configuration of the calculation method.


Two examples of energy consumption in a three-phase meter

If energy is imported on phases L1 and L2 (shown as red), and energy is exported on phase L3

(shown as blue) as shown to the left in the figure above, the calculation can be made according to

the methods described below.

The table below describes the different calculation methods of the total energy dependent on the

applied calculation method.

Calculation

method

Three-phase examples Description

Phase energy

consumption

Total energy

registration

Individual

import/export

The individual import/export calculation

method has one register for the positive

contributions and one for the negative

contributions.

Vector

summation

When using the vector summation

calculation, the positive contributions are

added and the negative contributions are

subtracted in the same way as by

electromechanical meters. Contributions

from e.g. solar energy installations will be

set off in the total energy calculation. This

calculation method is sensitive to incorrect

installation and manipulation.

Total

summation

The total summation calculation adds all

contributions to the positive register whether

one or more phases contributes with

negative energy.


Calculation methods in OMNIPOWER®

The calculation method for the two reactive energy types R+ (R12) and R- (R34) follows the same

principles as described in the table above for A+ and A-.

For the four reactive energy types R1, R2, R3 and R4, which can also be part of the load profile

logger, the calculation method is always based on the individual measuring principles independent

of the ordered calculation method for the four main energy types A+, A-, R+ and R-.

Therefore, if the meter is ordered with vector summation as calculation method, situations may still

occur where the meter, for example, records energy in both R1 and R4, but at the same time only

records energy in R12 and not in R34.

Important The configuration of the energy calculation method must be done when ordering the

meter and cannot be reconfigured afterwards.

Note For three-phase, three-wire meters (Aron), both direct and indirect meters, vector

summation must always be used, due to the physical design of the meters with only two

measuring systems, see "Connection diagrams ".

4.8.5 Mean power values

In the table "Main power registers in OMNIPOWER® ", the instantaneous values for the different

power registers in OMNIPOWER® are listed. Some of these values are also available as mean

values. The values are either averaged during the corresponding integration time for the load profile

or during the configurable log interval for the analysis logger.


OBIS code

P+mean The mean value of the positive active power during the legal integration

period.

kW 1.25.0

P-mean The mean value of the negative active power during the legal integration

period.

kW 2.25.0

Q+mean The mean value of the positive reactive power during the legal integration

period.

kvar 3.25.0

Q-mean The mean value of the negative reactive power during the legal integration

period.

kvar 4.25.0

S+mean The mean value of the positive apparent power during the legal integration

period.

kVA 9.25.0

S-mean The mean value of the negative apparent power during the legal integration

period.

kVA 10.25.0

Mean power values in OMNIPOWER®

16

27


The above mean values are also available for each phase L1-3.

4.8.6 Peak power values

OMNIPOWER® also registers the peak value for the power measurements. The measuring period

of the peak calculation follows the load profile integration period. For every integration period, the

mean power is calculated and then compared to the present peak value. If the new value exceeds

the present value, it replaces the present value.


OBIS code

P+max The active positive power consists of active power from quadrants 1 and 4. kW 1.6.0

1.6.x (tariff)

P-max The active negative power consists of active power from quadrants 2 and 3

(incl. Tariff 1 & 2).

kW 2.6.0

2.6.1

2.6.2

Q+max The reactive positive power consists of positive inductive power from

quadrant 1 and positive capacitive power from quadrant 2.

kvar 3.6.0

3.6.x (tariff)

Q-max The reactive negative power consists of negative inductive power from

quadrant 3 and negative capacitive power from quadrant 4 (incl. Tariff 1 &

2).

kvar 4.6.0

4.6.1

4.6.2

S+max The positive apparent power from quadrants 1 and 4. kVA 9.6.0

9.6.x (tariff)

S-max The negative apparent power from quadrants 2 and 3 kVA 10.6.0

Peak power values in OMNIPOWER®

The peak power values are reset at every debiting stop executed in the meter. For further

information about debiting stop and the debiting logger, please see “Monthly debiting logger”.

4.8.7 Energy tariff/TOU registers

For each main energy register; A+, A-, R+, R-, E+ and E-, OMNIPOWER® contains up to eight

deviated tariff registers. The use of tariff registers enables the possibility for time segmentation of

the total energy consumption. This is relevant when electricity is price differentiated according to

the time of use during a day, week or season. Which tariff that is to be active, can be controlled in

different ways:

· by hardware using a 230 VAC input signal

· by an on-demand remote command sent from a smart metering system

· by an internal tariff plan configuration in the meter

These options are described in the following sections.

34

34

34


4.8.7.1 Hardware-controlled – 230 VAC input

The available Kamstrup modules for OMNIPOWER® includes a 230 VAC input that provides a 2-

tariff or 4-tariff control option. The modules are:

· Tariff stand-alone (4-tariff)

· M-Bus module (2-tariff)

· RS485 module (2-tariff)

Tariff control by use of modules use the I/O ports of the module connector for changing the tariffs,

e.g. if a tariff control module prepared for 230 VAC is connected to 230 VAC. The inverted function

can also be selected. The control table is shown in this table:

Port 1:

Terminals 13 and 15

Port 2:

Terminals 33 and 15

Active tariff Active tariff

inverted

0 VAC 0 VAC T1 T4

230VAC 0 VAC T2 T3

0 VAC 230VAC T3 T2

230VAC 230VAC T4 T1

Tariff control table

Whether or not the active tariff is inverted, it is configured as part of the meter order form (Software

configuration , parameter Z3).

4.8.7.2 On-demand – system-controlled

With OMNIPOWER® is connected to a smart metering system, the actual tariff can be set by a

single remote command.

4.8.7.3 Internal tariff plan in the meter

OMNIPOWER® can contain up to three different tariff plans which can be selected on-site via the

sealable push button or remotely, e.g. via OMNIA®.

Each tariff plan can have one, two, three or four different season plans available. In one year, the

meter can shift up to eight times between the available season plans. Each season plan consists

of one, two or three types of days:

· Working days

· Non-working days

· Holidays.

A daily tariff plan can be made individually for each of the three different types of days. The tariff

plan setup is illustrated below:

84


Tariff plan setup for OMNIPOWER®

A daily tariff plan in the meter can contain up to 10 tariff shifts per day. The resolution of the shifting

is 1 minute.

4.9 Data loggers

OMNIPOWER® has a number of different data loggers:

· Load profile logger (15 minutes, half-hourly or hourly energy logger)

· Monthly debiting logger

· Daily, weekly or monthly debiting logger

· Daily logger

· Analysis logger

The loggers are different regarding the number of registers to be logged, the time interval between

the logs and the configuration possibilities. Each logger is described in the following sections.

Note All time stamps in data loggers are done in normal time and do not take any daylight light

saving time into account.

4.9.1 Load profile logger (1.1.99.1.0.255)

The load profile logger is based on energy readings, where the types of energy to be logged are

based on the meter configuration selected when ordering the meter. The load profile in

OMNIPOWER® is implemented according to the WELMEC software guide 11.2.

The integration period of the meter is changeable and can be set to 15, 30 or 60 minutes. The

period can be reconfigured after installation.

35

38

38

41


Depending on the chosen integration period and the number of energy types to be measured,

OMNIPOWER® contains a number of log entries which are converted to a number of days and

listed in the table below.

For OMNIPOWER® CT meters, the meter can be ordered to register either secondary or primary

values in the load profile logger.

Important This cannot be reconfigured afterwards.

Integration period

Energy type

15 min.

[Days]

30 min.

[Days]

60 min.

[Days]

A+ 275 550 1100

A+/A- 231 462 924

A+/R+ 231 462 924

A+/R1 231 462 924

A+/A-/R+/R- 175 350 700

A+/A-/R+/R- (hardware variant 2 meters) 180 360 720

A+/A-/R+/R-/R1/R2/R3/R4 122 244 488

Logging depth of load profile logger

Each log entry is also marked with a status marking, which is also implemented according to

WELMEC 11.2. It contains information regarding the quality of each specific log entry, e.g. any

voltage outage, overvoltages and undervoltages and any RTC adjustments executed during the

integration period.

For OMNIPOWER® direct meters, all energy registrations are made in kWh with two or three

decimals.

For OMNIPOWER® CT meters, it is possible to configure the load profile to register energy based

on either primary or secondary energy with reference to the current transformers. If primary energy

is chosen, the resolution is with two decimals, if secondary energy is chosen, the resolution is with

four decimals.

4.9.2 Monthly debiting logger (1.1.98.1.0.255) (2)

OMNIPOWER® has a debiting logger where the instantaneous values of a number of registers are

logged every time a debiting stop is executed. The registers that can be part of the debiting logger

are listed in the table below.

Various OBIS codes Energy registers OBIS codes Power registers OBIS codes

RTC w/quality

info1

0.1.1.0.0.255 Active energy A+1 1.1.1.8.0.255 P+ max1 1.1.1.6.0.255

Hour counter1 0.1.96.8.0.255 Active energy A-1 1.1.2.8.0.255 P+ max RTC1 1.1.1.6.0.255

Number of debiting

periods1,4

1.1.0.1.0.255 Reactive energy R+1 1.1.3.8.0.255 P+ max

accumulated1

1.1.1.2.0.255

Power threshold

counter11.1.96.51.2.255 Reactive energy R-1 1.1.4.8.0.255 P+ max Tariff 1-2

accumulated1

1.1.1.2.x.255


Various OBIS codes Energy registers OBIS codes Power registers OBIS codes

Pulse input1 1.1.0.128.1.255 A+ Tariff 1-41 1.1.1.8.x.255 Q+ max1 1.1.3.6.0.255

Current

transformer ratio1,2

1.1.0.4.2.255 R+ Tariff 1–41 1.1.3.8.x.255 Q+ max RTC1 1.1.3.6.0.255

Apparent energy E+1 1.1.9.8.0.255 Q+ max

accumulated1

1.1.3.2.0.255

Apparent energy E-1 1.1.10.8.0.255 P+ max Tariff 1-41,3 1.1.1.6.x.255

P+ max Tariff 1-4

RTC1,3

1.1.1.6.x.255

Q+ max Tariff 1-41,3 1.1.3.6.x.255

Q+ max Tariff 1-4

RTC1,3

1.1.3.6.x.255

S+ max1 1.1.9.6.0.255

S+ max RTC1 1.1.9.6.0.255

S- max1 1.1.10.6.0.255

S- max RTC1 1.1.10.6.0.255

P- max 1.1.2.6.0.255

P- max RTC 1.1.2.6.0.255

P- max Tariff 1-4 1.1.2.6.x.255

P- max Tariff 1-4

RTC

1.1.2.6.x.255

P- max accumulated 1.1.2.2.0.255

P- max accumulated

Tariff 1-2

1.1.2.2.x.255

Q- max 1.1.4.6.0.255

Q- max RTC 1.1.4.6.0.255

Q- max Tariff 1-4 1.1.4.6.x.255

Q- max Tariff 1-4

RTC

1.1.4.6.x.255

Actual power

(P1234)

1.1.15.7.0.255

Average power

(P1234)

1.1.15.25.0.255

Available registers in monthly debiting logger1 Included in the default monthly debiting logger setup.2 Register in OMNIPOWER® CT meter only.3 Only tarif f 1 and tarif f 2 are included in the default monthly logger setup.


4 The maximum value for this register is 99, after w hich the counter starts again at "0".

The interval between each debiting stop/debiting log can be controlled by the meter and can be set

to make an automatic log of the registers every month, every second month, every third month,

every half year or once a year.

The debiting stop can also be done on request, either by a command from a meter data

management (MDM) system, like OMNISOFT® VisionAir, or manually by using the sealable push

button if the meter is configured accordingly. The maximum number of log entries in the meter with

the default setup is 36. When the maximum number of logs has been reached, the meter

overwrites the oldest entries.

Maximum registers and associated RTC values are reset after each log entry. Maximum values

are reset to 0 and associated RTC values to 07-02-2136 06:28:15. If no new value is registered

during a log interval, the previously mentioned values will be logged.

4.9.3 Daily/weekly/monthly debiting logger (1.1.98.2.0.255)

In the same way, OMNIPOWER® also has a daily/weekly/monthly based debiting logger. The

registers that can be logged are listed in the table below.

Various OBIS codes Energy registers OBIS codes

RTC w/quality info 0.1.1.0.0.255 Active energy A+ 1.1.1.8.0.255

Hour counter 0.1.96.8.0.255 Active energy A- 1.1.2.8.0.255

Reactive energy R+ 1.1.3.8.0.255

Reactive energy R- 1.1.4.8.0.255

Reactive energy R1 1.1.5.8.0.255




Apparent energy E+ 1.1.9.8.0.255

Apparent energy E- 1.1.10.8.0.255

Active energy A+ Tariff 1 - 4 1.1.1.8.x.255

Active energy A- Tariff 1 - 4 1.1.2.8.x.255

Reactive energy R+ Tariff 1 - 4 1.1.3.8.x.255

Reactive energy R- Tariff 1 - 4 1.1.4.8.x.255

Reactive energy R1 Tariff 1-4 1.1.5.8.x.255




Apparent energy E+ Tariff 1-4 1.1.9.8.x.255

Apparent energy E- Tariff 1-4 1.1.10.8.x.255

Registers stored in debiting logger 2


The interval between each debiting stop is controlled by the meter and must be set to either daily,

weekly or monthly logging. The maximum number of entries in the logger is 175.

4.9.4 Daily Logger (1.1.98.128.0.255)

The daily logger contains a list of registers and has a fixed daily logging period. It is intended for

conventional data in automatic meter data readout in OMNIA®. The logger is configurable with

respect to the registers that shall be logged.

The registers available for the daily logger is shown in the table below.

Note For three-phase, three-wire meters (Aron), the interpretation of phases is: UL1=UL1-L2 (i.e.

the voltage between meter terminal 1 and 4), UL3=UL2-L3 (the voltage between meter

terminal 4 and 7) and UL2=UL1-L3 (i.e. the voltage between meter terminal 1 and 7). See

the connection diagram for Aron meters in "Connection diagrams ".

Note The registers marked with * are part of the default daily logger setup.

Registers OBIS codes

RTC w/quality info 0.1.1.0.0.255*

Number of debiting periods 1.1.0.1.0.255

Energy A1234 (|A+| + |A-|) 1.1.15.8.0.255*

Energy A-Net (|A+| - |A-|) 1.1.16.8.0.255*

Apparent energy import E+ 1.1.9.8.0.255*

Apparent energy export E- 1.1.10.8.0.255*

A+ Prepayment 1.1.130.0.0.255*

A+ Prepayment credit 1.1.130.0.1.255*

KMP energy format 1.1.134.0.1.255*

P+ max1 1.1.1.6.0.255*

P+ max RTC1 1.1.1.6.0.255*

P+ max accumulated2 1.1.1.2.0.255

P+ max Tariff 1-2 accumulated2 1.1.1.2.x.255

P- max1 1.1.2.6.0.255*

P- max RTC1 1.1.2.6.0.255*

P- max accumulated2 1.1.2.2.0.255

P- max Tariff 1-21 1.1.2.6.x.255

P- max Tariff 1-2 RTC1 1.1.2.6.x.255

P- max Tariff 1-2 accumulated2 1.1.2.2.x.255

UL1,24h minimum 1.1.32.3.130.255

UL1,24h minimum RTC 1.1.32.3.130.255

P+L1 @ UL1, 24h minimum 1.1.21.7.130.255

16



S+L1 @ UL1, 24h minimum 1.1.29.7.130.255

IL1 @ UL1, 24h minimum 1.1.31.7.130.255

UL1,24h maximum 1.1.32.6.131.255

UL1,24h Maximum RTC 1.1.32.6.131.255

P+L1 @ UL1, 24h maximum 1.1.21.7.131.255

S+L1 @ UL1, 24h maximum 1.1.29.7.131.255

IL1 @ UL1, 24h maximum 1.1.31.7.131.255

UL2,24h minimum 1.1.52.3.130.255

UL2,24h minimum RTC 1.1.52.3.130.255

P+L2 @ UL2, 24h minimum 1.1.41.7.130.255

S+L2 @ UL2, 24h minimum 1.1.49.7.130.255

IL2 @ UL2, 24h minimum 1.1.51.7.130.255

UL2,24h maximum 1.1.52.6.131.255

UL2,24h Maximum RTC 1.1.52.6.131.255

P+L2 @ UL2, 24h maximum 1.1.41.7.131.255

S+L2 @ UL2, 24h maximum 1.1.49.7.131.255

IL2 @ UL2 , 24h maximum 1.1.51.7.131.255

UL3,24h minimum 1.1.72.3.130.255

UL3,24h minimum RTC 1.1.72.3.130.255

P+L3 @ UL3, 24h minimum 1.1.61.7.130.255

S+L3 @ UL3, 24h minimum 1.1.69.7.130.255

IL3 @ UL3, 24h minimum 1.1.71.7.130.255



UL3,24h maximum 1.1.72.6.131.255

UL3,24h maximum RTC 1.1.72.6.131.255

P+L3 @ UL3, 24h maximum 1.1.61.7.131.255

S+L3 @ UL3, 24h maximum 1.1.69.7.131.255

IL3 @ UL3, 24h maximum 1.1.71.7.131.255

Available registers for daily logger1 Register is only reset once a debiting stop is executed. 2 Register is only updated once a debiting stop is executed.

Maximum/minimum registers and associated RTC values are reset after each log entry. Maximum

values are reset to 0, minimum values to 4.294.967.295 and associated RTC values to 07-02-2136

06:28:15. If no new maximum/minimum value is registered during a log interval, the previously

mentioned values will be logged.

4.9.5 Analysis logger (1.1.99.1.1.255)

The analysis logger allows you to configure the registers to be logged and the log interval. You can

configure:

· Up to 24 different registers*. * Firmware revisions earlier than J1 for direct meters only support 16 different registers.

· The log intervals: 5 minutes, 10 minutes, 15 minutes, 30 minutes, 60 minutes or daily(independent of the load profile settings).


Pulse input 1.1.0.128.1.255

Hour counter 0.1.96.8.0.255

Active energy A+ 1.1.1.8.0.255

Active energy A- 1.1.2.8.0.255

Reactive energy R+ 1.1.3.8.0.255

Reactive energy R- 1.1.4.8.0.255





A+ Tariff 1-8 1.1.1.8.x.255

A- Tariff 1-8 1.1.2.8.x.255

R+ Tariff 1-8 1.1.3.8.x.255

R- Tariff 1-8 1.1.4.8.x.255



Active energy A1423 1.1.15.8.0.255

Active energy A+Net 1.1.16.8.0.255

Apparent energy E+ 1.1.9.8.0.255

Apparent energy E- 1.1.10.8.0.255

Actual power P+ 1.1.1.7.0.255

Actual power P- 1.1.2.7.0.255

Actual power Q+ 1.1.3.7.0.255

Actual power Q- 1.1.4.7.0.255

Power Factor Avg 1.1.13.25.0.255

A+L1A+L2A+L3

1.1.21.8.0.255

1.1.41.8.0.255

1.1.61.8.0.255

A-L1A-L2A-L3

1.1.22.8.0.255

1.1.42.8.0.255

1.1.62.8.0.255

P+L1, average

P+L2, average

P+L3 average

1.1.21.25.0.255

1.1.41.25.0.255

1.1.61.25.0.255

P+L1, minimum +RTC

P+L2, minimum +RTC

P+L3 minimum +RTC

1.1.21.3.128.255

1.1.41.3.128.255

1.1.61.3.128.255

P+L1, maximum +RTC

P+L2, maximum +RTC

P+L3 maximum +RTC

1.1.21.6.128.255

1.1.41.6.128.255

1.1.61.6.128.255

P-L1,

P-L2,

P-L3

1.1.22.25.0.255

1.1.42.25.0.255

1.1.62.25.0.255

Q+L1,

Q+L2,

Q+L3

1.1.23.25.0.255

1.1.43.25.0.255

1.1.63.25.0.255

Q-L1,

Q-L2,

Q-L3

1.1.24.25.0.255

1.1.44.25.0.255

1.1.64.25.0.255



S+L1, average

S+L2, average

S+L3, average

1.1.29.25.0.255

1.1.49.25.0.255

1.1.69.25.0.255

S+L1, minimum +RTC

S+L2, minimum +RTC

S+L3 minimum +RTC

1.1.29.3.128.255

1.1.49.3.128.255

1.1.69.3.128.255

S+L1, maximum +RTC

S+L2, maximum +RTC

S+L3 maximum +RTC

1.1.29.6.128.255

1.1.49.6.128.255

1.1.69.6.128.255

S-L1, average

S-L2, average

S-L3, average

1.1.30.25.0.255

1.1.50.25.0.255

1.1.70.25.0.255

Cut-off state 1.1.128.0.0.255

P+ max, daily 1.1.1.16.0.255

P+ min., daily 1.1.1.13.0.255

P+ max, daily – RTC 1.1.1.16.0.255

P- min.,daily – RTC 1.1.1.13.0.255

IL1, average

IL2, average

IL3 average

1.1.31.25.0.255

1.1.51.25.0.255

1.1.71.25.0.255

IL1, minimum + RTC

IL2, minimum + RTC

IL3, minimum + RTC

1.1.31.3.128.255

1.1.51.3.128.255

1.1.71.3.128.255

IL1, maximum + RTC

IL2, maximum + RTC

IL3, maximum + RTC

1.1.31.6.128.255

1.1.51.6.128.255

1.1.71.6.128.255

UL1, average

UL2, average

UL3 average

1.1.32.25.0.255

1.1.52.25.0.255

1.1.72.25.0.255

UL1, minimum + RTC 1.1.32.3.128.255



UL2, minimum + RTC

UL3 minimum + RTC

1.1.52.3.128.255

1.1.72.3.128.255

P+L1 @UL1,minP+L2 @UL2,minP+L3 @UL3,min

1.1.21.7.128.255

1.1.41.7.128.255

1.1.61.7.128.255

S+L1 @UL1,minS+L2 @UL2,minS+L3 @UL3,min

1.1.29.7.128.255

1.1.49.7.128.255

1.1.69.7.128.255

IL1 @UL1,minIL2 @UL2,minIL3 @UL3,min

1.1.31.7.128.255

1.1.51.7.128.255

1.1.71.7.128.255

UL1, maximum + RTC

UL2, maximum + RTC

UL3 maximum + RTC

1.1.32.6.129.255

1.1.52.6.129.255

1.1.72.6.129.255

P+L1 @UL1,maxP+L2 @UL2,maxP+L3 @UL3,max

1.1.21.7.129.255

1.1.41.7.129.255

1.1.61.7.129.255

S+L1 @UL1,maxS+L2 @UL2,maxS+L3 @UL3,max

1.1.29.7.129.255

1.1.49.7.129.255

1.1.69.7.129.255

IL1 @UL1,maxIL2 @UL2,maxIL3 @UL3,max

1.1.31.7.129.255

1.1.51.7.129.255

1.1.71.7.129.255

PFL1,

PFL2,

PFL3

1.1.33.25.0.255

1.1.53.25.0.255

1.1.73.25.0.255

THDUL1,

THDUL2,

THDUL3

1.1.32.24.124.255

1.1.52.24.124.255

1.1.72.24.124.255

THDIL1,

THDIL2,

1.1.31.24.124.255

1.1.51.24.124.255

1.1.71.24.124.255



THDIL3

Frequency 1.1.14.25.0.255

Available registers for analysis logger

For three-phase, three-wire meters (Aron), the interpretation of phases is: UL1=UL1-L2 (i.e. the

voltage between meter terminal 1 and 4), UL3=UL2-L3 (the voltage between meter terminal 4 and

7) and UL2=UL1-L3 (i.e. the voltage between meter terminal 1 and 7). See the connection diagram

for Aron meters in "Connection diagrams ".

The logging depth of the analysis logger depends on the log interval and the number of registers in

the analysis logger. The meter is preconfigured from the factory regarding the registers to be

logged and the interval by which they are logged. These settings can, however, be reconfigured. By

default, the log interval is set to 15 minutes.

You can see the default setup of the analysis logger in the table below.

Meter type OMNIPOWER® single-phase OMNIPOWER® three-phaseRegisters in the

load profile logger

1

register

2

registers

4

registers

1

register

2

registers

4

registers

Default registers in

the analysis logger

A+ A+/A A+/R+ A+/A-/R+/R- A+ A+/A A+/R+ A+/A-/R+/R

-

Actual power P+ X X X X X X X X

Actual power P- X X X X

Actual power Q+ X X X X

Actual power Q- X X

Average voltage

L1

X X X X X X X X

Average voltage

L2

X X X X

Average voltage

L3

X X X X

Average current

L1

X X X X X X X X

Average current

L2

X X X X

Average current

L3

X X X X

Logging depth of

analysis logger

- - - - - - - -

16


Meter type OMNIPOWER® single-phase OMNIPOWER® three-phase

[Days]

Default setup for analysis logger

The mean phase voltage and mean phase current are calculated as the mean value during the log

interval period configured for the analysis logger. The phase currents are shown as absolute

values without indicating the direction of the current.

Maximum/minimum registers and associated RTC values are reset after each log entry. Maximum

values are reset to 0, minimum values to 4.294.967.295 and associated RTC values to 07-02-2136

06:28:15. If no new maximum/minimum value is registered during a log interval, the previously

mentioned values will be logged.

4.10 Meter readout

OMNIPOWER® offers a range of options regarding meter data readout. It spans from simple

display reading to advanced remote readout for smart metering systems.

4.10.1 Manual display readout

The OMNIPOWER® display can show all relevant meter data, e.g. power and energy, phase

currents and voltages, meter number, etc. Even the load profile and the debiting logger can be read

out in the display. The complete design of the available segments in the display is shown in the

figure below and the different display segments are described in the following sections.

OMNIPOWER® display


4.10.2 9-digit value field

This field is used for displaying all kinds of register values.

· Meter energy is stated in [6.1], [6.3] [7.0] or [7.2] format with either “kWh” or “kvar” as unit.

· Power is shown with [2.3] format (00.000) and either “kW” or “kvar” as unit.

· Date/time can also be shown in the display and is stated according to the formats YYYY:MM:DDand HH:MM:SS, respectively. In both cases without any units shown.

· Register values like meter number, special data, etc. are indicated by eight digits also withoutany unit.

· The value field can be configured to show leading zeroes of all energy readings. What isshown in the value fields depends on the configuration of the display.

The configuration of the display is explained further in "Display configuration ". The display

configuration can also be remotely updated after installation of the meter (from the meter data

management (MDM) system OMNISOFT® VisionAir).

4.10.3 Unit field

This field is used for displaying the units of registers in the value field.

4.10.4 Object identification field

This field is used for identifying the value in the value field. OBIS codes are used in connection with

the identification.

4.10.5 Quadrant reading

The total current load is indicated by the arrows for +P (imported active power), -P (exported active

power), +Q (inductive reactive power) and –Q (capacitive reactive power), respectively.

The quadrant reading is an instantaneous total value for all three phases. The reading is not active

when the load is below the minimum limit of 10 mA RMS.

It is configurable whether the quadrant indication is visible in the display.

4.10.6 Text field

This field is used either for additional information about the unit field regarding values in the value

field or for text information. In the latter case, text messages are shown as scrolling text in the

field.

90


4.10.7 Module indication

This indicates whether a module is communicating with the meter, and if this is the case which

module, e.g. internal radio, primary module or CCC-module.

Note This feature is not yet activated.

4.10.8 Error symbol

This is only used internally by Kamstrup A/S.

4.10.9 Breaker symbol

If the meter is configured with an internal breaker, the position of the breaker is indicated as either

connected or disconnected. However, if the smart disconnect functionality is disabled, both

symbols are off.

Note This is not available for OMNIPOWER® CT meters.

4.10.10 Tamper symbol

This indicates either a magnetic field near the meter or if the meter cover has been removed from

the meter.

4.10.11 Radio network symbol

If a meter is to be used in an OMNICON® Radio Mesh Network, this indicates the connection status

of the meter with the network.

4.10.12 Prepayment symbol

This indicates whether the prepayment functionality is activated.

Note This is not available for OMNIPOWER® CT meters.

4.10.13 Tariff/TOU indication

This indicates the currently active tariff, i.e. either T1, T2, T3, T4, T5, T6, T7 or T8. The tariff

reading is updated every 10 seconds. This means that it may take up to 10 seconds from a tariff

shift has been carried out until the current tariff is displayed.

The tariff indication is switched off if display configuration without tariff reading has been selected.


4.10.14 Mains voltage reading

The mains voltage readings per phase L1, L2 and L3 indicates whether voltage is applied to the

individual phase input terminal or not.





Indications L1, L2, L3 Indicates that

On The voltage is above minimum limit (160VAC).

Off The voltage is below minimum limit (160VAC).

Main phase voltage indication

The minimum voltage limit is 160 VAC ±5 %. If the voltage remains below the minimum limit for

more than 1 second in all phases, the processor shuts down and the meter is reset.

4.10.15 Phase current indication

The direction of the current for each phase is shown with these indicators. It can be useful when

checking if inputs and outputs have been installed correctly.

Indications

Indicates that

On The load is above minimum limit.

Off The load is below minimum limit.

Phase current indication

The minimum load limit for the phase current indication is approximately 2.3 W (0.6W for

OMNIPOWER® CT meters). If the phase current is lower than this value, the energy registration

stops, and the phase current indication turns off in the display.

Note Due to the special design of three-phase, three-wire meters with only two measuring

systems, i.e. Aron meters, the phase current indicators can in some situations (with high

phase angle between current and voltage) show misleading information.

4.10.16 Phase sequence indication

This shows the phase sequence of the input phases. If both symbols are off, this indicates that no

sequence could be clearly recognized. The reason could be that one or two phases are missing on

the input.

16


4.10.17 Protocols

The following communication protocols are available with OMNIPOWER®.

· Kamstrup Meter Protocol (KMP)

· DLMS/COSEM

· EN 62056-21 (1107) Mode A & C

4.10.17.1 Kamstrup Meter Protocol (KMP)

Kamstrup Meter Protocol (KMP) is a communication protocol that is suited for communication with

OMNIPOWER®. It provides access to all registers in the meter and enables programming and

setup.

For further information about this protocol, please contact Kamstrup A/S.

4.10.17.2 DLMS

The DLMS protocol provides access to most registers and loggers in the meter and to most of the

configuration options as well. For details, please see the “DLMS Protocol description” (document

no. 5512-1424). For further information about the DLMS protocol for OMNIPOWER®, please

contact Kamstrup A/S.

4.10.17.3 1107

The 1107 protocol provides access to most registers in the meter and enables configuration and

setup. For details, please see the IEC 1107 Protocol description (document no. 5512-1458). For

requesting the 1107 protocol for OMNIPOWER® meters, please contact Kamstrup A/S.

Note The protocol is not supported for meter firmware number 50981173, 50981165 and

50981251.

4.10.18 Local readout via optical interface – METERTOOL OMNIPOWER®

With METERTOOL OMNIPOWER®, it is possible to read out all meter relevant data via the optical

interface. This tool is also suitable for configuration of the meter. For details, please see the

installation and user guide "METERTOOL OMNIPOWER®” (doc. 5512-1213).

For more information about METERTOOL OMNIPOWER®, please contact KAMSTRUP A/S.

4.10.19 Integrated OMNICON® radio mesh connectivity

Meters are delivered with integrated OMNICON® radio mesh connectivity. When connected to the

OMNIA® smart grid platform, the full range of advanced features becomes available.

50

50

50


4.10.20 Integrated OMNICON® point-to-point connectivity

Meters are delivered with OMNICON® point-to-point connectivity modules as shown in the figure

below. When connected to the OMNIA® smart grid platform, the full range of advanced features

becomes available.

Point-to-point communication in OMNIA® Suite

The communication module can be delivered pre-mounted in the meter, or it can be mounted after

the meter is installed. The post-mounting of the modules can be done without removing the power

to the meter terminal connection.

4.10.21 Full encryption on all interfaces

OMNIPOWER® with software number 55981173, 50981165 and 50981251 introduces full data

encryption on all communication interfaces including the primary module port, the CCC module

port and the optical interface. The encryption method used is AES 128-bit.

It covers readout of all consumption/production data, read and write possibilities of configuration

parameters and control commands like disconnect/reconnect of the internal breaker of the meter.

OMNIA® Suite supports full readout, configuration and control of encrypted OMNIPOWER®

meters. For 3rd party meter data management (MDM) systems to be able to support encrypted

meters, it is required that the systems connect to OMNISOFT® Key Management Service (KMS),

which will allow the MDM system to access all unique encryption keys for the relevant meters.

For more information about encrypted meters and KMS, please contact Kamstrup A/S.

4.10.22 M-Bus and RS-485 connectivity

As an option, OMNIPOWER® can be delivered with M-Bus or RS-485 connectivity modules. The

M-Bus module communicates through the EN13757-2/3 protocol. The RS-485 module can be

used with the KMP, DLMS and 1107 protocols.


4.11 Modularity options

OMNIPOWER® has two independent module areas available for communication. By default, both

module areas are available on all OMNIPOWER® meter types.

4.11.1 Primary modules

The primary module area can be used for communication modules as described in the previous

section, but it can also be used for tariff control modules, load control modules, etc.

4.11.2 CCC modules

The second module area, which is shown in the figure below, offers access to the Consumer

Communication Channel (CCC).

CCC-module area in OMNIPOWER®

CCC-modules are intended for in-home communication as shown below. The communication can

be one way, e.g. to an in-home display, or it can be two-way for intelligent control of e.g. relays in

the home.

CCC-modules also enable the utilities to send consumer-related information, e.g. price signals, to

in-home displays directly from their meter data management (MDM) system or other business

systems.


CCC-module in OMNIA® Suite

A suitable technology for in-home communication is ZigBee® Smart Energy or similar.

4.12 Disconnect functionality

The following description applies to OMNIPOWER® direct meters with integrated breakers.

Meters with integrated breakers can disconnect and reconnect the consumer’s supply. All meters

with integrated breaker are marked on the front of the meter as shown below.

The breaker is controlled by the main processor of the meter and is bistable, i.e. it maintains its

status (connected/disconnected) independently of the main supply status of the meter.

The integrated breaker disconnects all the output phases in the meter while the neutral connection

is not disconnected.

Important The breaker must not be used for safety cut-off.


For both OMNIPOWER® three-phase and OMNIPOWER® single-phase meters, the integrated

breakers are approved according to EN 62055-31, Annex C for UC3 breaking capabilities. This

means that the meter fulfills following:

· 10.000 makes-and-breaks cycles @ 100A (5.000 @ PF=1.0 and 5.000 @ PF=0.5 inductive).

· Short circuit current carrying capacity 6kA/3kA (Test1/Test2).

The UC3 approval documents can be handed out by Kamstrup A/S on request.

The OMNIPOWER® three-phase DIN rail meter is approved according to EN62055-31 for UC2

breaking capabilities.

4.12.1 Disconnect function

OMNIPOWER® can be delivered with integrated breakers. It is possible to disconnect the breaker

in the following ways:

· Manually by activating the left push button.

· Remotely from a smart metering system.

· By smart disconnect, i.e. intelligent disconnection when voltage, current or power exceeds apreconfigured limit.

· By the integrated prepayment option.

When the breaker is disconnected, it is possible to reconnect the breaker in the following ways:

· Manually by activating the left push button.

· Remotely via a release command and an additional reconnect command.

· With a combination of a release command sent from a smart metering system and a manualreconnect on the push button.

· Automatically after current and power level are back to normal or credit (if prepayment isactivated) is restored.

Independently of the way of reconnect, the reconnection time is minimum 5 seconds. It is

configurable which of these options are available in a meter.

The different control options are described in details in the following sections.

4.12.2 Manual disconnection and reconnection

It is possible to disconnect and reconnect the breakers manually. This is done in the following

ways:

Manual disconnection1. On the meter, select the shown display reading by activating the left push button.


2. Activate the left push button for approx. 6 seconds. This disconnects the relays, and the redLED turns on.

Manual reconnection1. On the meter, select the primary display reading when the red LED is flashing.

2. Activate the left push button for 6 seconds until the relays are connected and the red LED turnsoff.

4.12.3 Remote disconnection from a smart metering system

For OMNIPOWER® meters with integrated breakers, it is also possible to disconnect, release and

reconnect the breaker remotely. As a safety precaution, the remote disconnect functionality in

OMNIA® is securely protected by encrypted communication.

4.12.4 Smart disconnect

OMNIPOWER® includes a smart disconnect feature that disconnects the breakers if either the

total current or power exceeds a preconfigured limit.

4.12.5 Disconnection basis

The “disconnection basis” setup choice defines whether smart disconnect is enabled or disabled,

and (if enabled) on which basis the smart disconnect is affected. It is possible to select:

· No function: The smart disconnect function is disabled.

· Current-controlled: Smart disconnect is affected when a configured current limit is exceeded.

· Power-controlled: Smart disconnect is affected when a configured power limit is exceeded.

· Voltage-controlled: Smart disconnect is affected when a configured phase voltage limit isexceeded.

· Prepayment: The prepayment function controls the disconnection.

The disconnection basis is selected as part of the smart disconnect configuration. By default,

OMNIPOWER® is provided with the smart disconnect functionality disabled. If the function is to be

used, it can either be enabled from the factory at delivery, activated remotely or locally with

METERTOOL OMNIPOWER®.


4.12.6 Current-controlled disconnection

Current-controlled disconnection is based on RMS current with average calculation every 1

second. Disconnection is affected if one of the phase currents IL1, IL2 or IL3 exceeds the limit

Id*kx for a configured time period; t1, t1+t2 or t1+t2+t3.

4.12.7 Power-controlled disconnection

Power-controlled disconnection is based on the total power in all phases. Disconnection is

affected if the total phase power exceeds the limit Id*kx for a configured time period; t1, t1+t2 or

t1+t2+t3.

At smart disconnect configuration, the disconnect current Idisconnect (Id) or the disconnect power

Pdisconnect (Pd) is set, and it must be determined whether the smart disconnect is to be based

on either current or power. The breaker then disconnects the supply when Id or Pd is exceeded.

OBIS code Register Min. value Max. value

1.1.128.0.13.255 Idisconnect 0 A 80 A

1.1.128.0.13.255 Pdisconnect 0 kW 80 kW

Configuration limits for smart disconnect

4.12.8 Overvoltage disconnection

OMNIPOWER® also offers an option for automatic disconnection in case of an overvoltage. The

overvoltage disconnection and reconnection are based on average values of the phase voltages,

and the activations can therefore be delayed by configuration of the sample time parameters called

“Sample-time disconnect” and “Sample-time reconnect”. The voltage thresholds for disconnection

and reconnection are also configurable.

Example:

In the example shown below, the four configuration parameters are set to following values:

· Overvoltage disconnect level: 270V

· Overvoltage reconnect level: 260V

· Overvoltage sample-time for disconnect: 2 sec.

· Overvoltage sample-time for reconnect: 5 sec.


Example of overvoltage disconnect and reconnect

The configuration parameters have the range and resolution shown in the table below.

OBIS code Parameter Value range (resolution) Default value

1.1.128.0.19.255 Overvoltage disconnect threshold 260-320V (1 V) 285V

1.1.128.0.20.255 Overvoltage sample time for

disconnect

1 – 3600 sec (1 sec) 1 sec

1.1.128.0.21.255 Overvoltage reconnect threshold 250-270V (1 V) 265V

1.1.128.0.22.255 Overvoltage sample time for reconnect 1 – 3600 sec (1 sec) 60 sec

Overvoltage disconnect configuration parameters

Note By default, the overvoltage disconnect functionality is deactivated. It can be activated for

METERTOOL OMNIPOWER®.

4.12.9 Delayed disconnection

OMNIPOWER® can be configured to delay the disconnection and to differentiate the disconnection

characteristics. This is done with configurable multiplication factors for both time : t1, t2, t3 and

current/power factors: k1, k2, k3.


1.1.128.0.2.255

1.1.128.0.3.255

1.1.128.0.4.255

k1,

k2,

k3

0 9.9

1.1.128.0.5.255 t1, 0 65535



1.1.128.0.6.255

1.1.128.0.7.255

t2,

t3 [sec.]

Multiplication factors for smart disconnect

The following conditions for the factors must be met at configuration:

t1 =< t2 =< t3 and k3 =< k2 =< k1

The meter disconnects the supply if one of the below conditions is met for current or power,

respectively.

Current Power

I > Id * k3 and t > t1 + t2 + t3 P > Pd * k3 and t > t1 + t2 + t3

I > Id * k2 and t > t1 + t2 P > Pd * k2 and t > t1 + t2

I > Id * k1 and t > t1 P > Pd * k1 and t > t1

Disconnect conditions for OMNIPOWER®

The conditions in the table above are also illustrated in this figure:

Differentiation of smart disconnection

4.12.10 Reconnection

Reconnection can be configured to be either manual or automatic. In OMNIPOWER® meters that

are part of a smart metering system, the meters can be configured to allow manual reconnection

(provided that the meter is first released for manual reconnection by the utility). The meter is

released by sending a remote command to the meter.


It is possible to configure a mandatory time delay called TConnectWait which indicates the

minimum time before a reconnect can be executed.

OBIS code Register Min. value Max. value Default value

1.1.128.0.8.255 TConnectWait 0 A 80 A

The setup for TConnectWait used for delay in reconnection of breakers

4.12.11 Disconnection on meters with APS

For OMNIPOWER® with auxiliary power supply (APS), the disconnection functionality differs from

the description in the previous sections.

If OMNIPOWER® with APS is supplied by main terminals L1, L2 and L3, the functionality is the

same as mentioned earlier. When, however, this meter is supplied from the APS input, no breaker

activation is possible, neither disconnection nor reconnection.

4.12.12 Event logger for disconnect/connect history (1.1.99.98.5.255)

OMNIPOWER® with breaker includes a logger that registers all events related to the disconnect

functionality. For each event, either a disconnection, a release or a reconnection, the meter logs an

ID, a time stamp, the disconnect state and the connection feedback.

The size of this logger is 200 log entries.

4.12.13 Prepayment

The prepayment functionality is to be used with a smart metering system. By default, the

prepayment function is disabled, but it can be activated and deactivated as required.

Note Prepayment is only possible for meters with internal breaker and will not work together

with tariffs.

4.12.14 Prepayment principle

Prepayment is based on the specific prepayment register A14prepayment.

When enabling the prepayment functionality, A14prepayment must be “loaded” with a number of

kWh. This can only be done by using a system that supports the functionality.

As soon as the register contains a number of kWh and the functionality is enabled in the meter, the

register starts counting down as the energy is consumed.

When A14prepayment has reached 0 kWh, the supply is disconnected, and a new value must be

programmed for the register.


When prepayment is activated, the prepayment register A14prepayment must be activated in the

display settings by activating a display setup that includes the prepayment register. If a display

setup with the prepayment register is activated, the register is, however, only shown when

prepayment is enabled.

When prepayment is activated in the meter, the “PP” symbol is shown in the display.

The “PP” symbol shown in the meter display

The unit in the display is “kWh”, and “PAY” is shown in the text field.

The prepayment is based on total energy consumption and does not support tariffs. Therefore, the

functionality is disregarded if the meter is configured for tariffs.

A14prepayment can be configured to disconnect only on working days, i.e. not on non-working

days, holidays or exception days. It is also possible to set a time slot, e.g. from 10:00 PM to 8:00

AM the following day where the disconnection will not happen.

If A14prepayment reaches zero within one of the above mentioned exceptions, the disconnection

happens on the next working day. In the meantime, the credit register A14prepayment,credit starts

registering the energy that is consumed until disconnection takes place. When adding new kWh to

the meter, the meter takes any consumption in the credit register into account. The meter

subtracts the value in A14prepayment,credit from the added amount of kWh and put the remaining

kWh in A14prepayment.

If A14prepayment has reached 0 kWh, and the breakers are disconnected, it is possible to

reconnect under certain conditions. First, the load must be decreased below a defined limit called

Iexception or Pexception. The limits are configurable within the range given in the table below.

After the load is limited, it is possible to reconnect the meter and by that still be able to use a

minimum of power. Be sure to keep the consumption below the limit, or the meter will disconnect

again. The duration in which the exception for current and power, respectively, can be active is

however limited by a configurable number called tprepayment. When the limit is exceeded, the

consumer is disconnected until new kWh are added to the meter. In the intervening period, the

consumed energy is also registered in A14prepayment,credit.


1.1.128.0.12.255 Iexception 0 A 80 A

1.1.128.0.12.255 Pexception 0 kW 80 kW



1.1.128.0.9.255 tprepayment 0 255 days

Configurable parameters for smart disconnect

4.13 Power quality measurements

OMNIPOWER® is equipped with a supply power quality measurement tool. It is based on the

requirements in EN50160 regarding power quality delivered from utilities and includes

measurement of the following:

· Frequency variations

· Long-term and short-term overvoltage and undervoltage

· Power outages

· Rapid voltage change

· Supply voltage unbalance

· Total harmonic distortion (THD)

· Neutral fault detection

· Power factor

These quality measurements are described in the following sections. The power quality detection

and registration in OMNIPOWER® is based on events, i.e. information is only registered if an

unexpected situation appears. Some events are registered with detailed information like time

stamp and voltage level information, while other events are registered as a counting number in an

occurrence counter.

4.13.1 Frequency measurements

Normally, frequency variations will not be relevant as most grids are synchronous connected to an

interconnected grid system. However, in special cases where the grid is isolated, frequency

measurements are relevant.

OMNIPOWER® measures a 10-second mean value of the line frequency and compares this value

with the limits given in EN50160. The total number of events where this 10-second mean value is

outside the limits is registered in the occurrence counter in the meter.

It is also possible to include the line frequency in the analysis logger, where the meter will log an

average value according to the log interval configured for the analysis logger.

4.13.2 Voltage variations

OMNIPOWER® continuously (every second) updates the supply voltages at each phase and

detects and registers any deviations from a set of user-defined voltage limits, i.e. a deviation can

be either an overvoltage or an undervoltage.






4.13.2.1 Long-term deviations

Long-term deviations are related to a mean value of the phase voltage. Therefore, it is also called

mean time deviation. The average time, Utime-period,mean is configurable in the span from 10

seconds and up to 30 minutes. The mean value is calculated for every window and for each time

the value is outside the limits, i.e >Uhigh,mean or <Ulow,mean, the event is registered in the

voltage quality logger.

The figure below shows an example of a phase voltage that varies in time. In this period, the

average time is set to 10 seconds and the first and the third period is registered as deviations.

Example of long-term voltage deviation. Average time period is 10 seconds

A long-term deviation is registered in the voltage quality logger in the form of a time stamp (start

time), a mean value, a maximum value and a minimum value for the period.

4.13.2.2 Short-term deviations

OMNIPOWER® also detects and registers deviations that last shorter than the average time for

mean value deviations. For a description, please see "Long-term deviations ". This is described

as short-term or single value deviation.

Three examples of short-term voltage deviations are shown in the figure below. In a case, where

the voltage is outside the limits for several seconds, the first value, maximum/minimum value and

last value is registered. Every value is registered with a time stamp.

16

62


Example of short-term voltage deviations

Deviations that last shorter than 1 second is registered as sags and swells, which is described in

"Voltage sags and swells with a duration 100 ms – 1 second ".

4.13.3 Voltage outage

OMNIPOWER® detects all voltage outages, whether they are happening on one, two or three

phases. All events are registered in the voltage quality logger as two events; one for outage of the

voltage and one for reestablishment of the voltage.

The voltage detection level depends on the event. If the outage is on one or two phases (i.e. the

meter is still powered by the third phase), the registration level is a configurable value between 50-

160 V. If the power outage is on all phases, the detection level is approximately 160 V. The

detection levels are illustrated in the figure below.

Detection levels for one phase and three phase voltage outage

It is possible to configure the time the voltage outage shall be present before the event is logged.

The value can be configured in the interval from 0 second – 30 minutes.

65


All detected voltage outages are also registered in one of two occurrence counters that register the

number of voltage outages. According to EN50160, voltage outages are divided into short voltage

registered in one of the two categories.

Note For three-phase, three-wire meters (Aron), the voltage outage detection is only 100% valid

for outages on phase L1 or phase L3. As the phase L2 voltage is the voltage between pin 1

and pin 7, it is not measured by its own measuring system (according to the connection

diagrams in "Connection diagrams "). Depending on the actual load on the installation, a

removal of L2 wire can be therefore detected as a phase voltage outage on either phase

L1 or phase L3, or it can be detected an all phase outage.

4.13.4 Configuration of voltage quality measurements

As described in the previous sections, the voltage quality measurements require that a list of

configurable parameters is set. The list is given in the table below and the figure shows the visual

function of the parameters.

Parameter Description Min.

value

Max.

value

Defaul

t

value

Uhigh,mean The voltage level for overvoltage detection according to

mean voltage deviation (in +% of nominal voltage).

232.3 V

+1%

276 V

+20%

253 V

+10%

Ulow,mean The voltage level for undervoltage detection according to

mean voltage deviation (in % of nominal voltage).

184 V

- 20%

227.7 V

-1%

207 V

-10%

Utime-period,mean The time period for calculating the mean voltage. 10 sec. 30 min. 10

min.

Uhigh,sv The voltage level for overvoltage detection according to

short-term deviation (in +% of nominal voltage).

232.3 V

+1%

276 V

+20%

253 V

+10%

Ulow,sv The voltage level for undervoltage detection according to

short-term deviation (in -% of nominal voltage).

184 V

- 20%

227.7 V

-1%

207 V

-10%

Uoutagelevel The voltage level for a voltage outage that happens on one

or two phases (for three-phase meters)

50 V 160 V 50 V

Uoutage,timethreshold The time that a voltage outage has to be present before it

is registered in the voltage quality logger.

0 sec. 30 min. 10

sec.

Configurable parameters for voltage quality measurements

16


Configurable parameters for voltage quality measurements

The parameters can be configured remotely by using an automatic meter reading (AMR) system or

locally using METERTOOL OMNIPOWER®.

4.13.4.1 Voltage sags and swells with a duration 100 ms – 1 second

OMNIPOWER® also detects and registers the number of voltage sags (dips) and voltage swells,

which are events where phase voltage drops below 20% of Un or rises above 20% of Un for a

period shorter than one minute.

Sags and swells that last for more than 1 second are registered in the voltage quality logger as

described in "Short-term deviations ". Sags and swells that last from 100 milliseconds to 1

second are detected and registered in one of two occurrence registers.

Voltage sags and swell are not registered with a time stamp or any indication of voltage level.

Instead, the number of each event is registered in the meter. OMNIPOWER® can register one sag

and swell per second.

4.13.5 Rapid voltage change

A rapid voltage change is defined as a change in the phase voltage within the limits set for

overvoltage and undervoltage detection. For OMNIPOWER®, a rapid voltage change is defined as

a change of 5% or more, between two subsequent samples of the phase voltage, i.e. DV > 11.5 V.

Every rapid voltage change is registered in an occurrence counter register and this register is

logged in the occurrence counter logger.

62


4.13.6 Supply voltage unbalance

Supply voltage unbalance is a number for the balance between the three-phase voltage according

to voltage level for each phase and the phase shift between the three voltages. EN50160 describes

that the supply voltage unbalance must not exceed 2% when calculated as a 10-minute mean

value.

OMNIPOWER® continuously measures the supply voltage unbalance. If the mean value exceeds

the limit, the event is registered in an occurrence counter register and the register is logged in the

occurrence counter logger.

4.13.7 Total harmonic distortion (THD)

OMNIPOWER® also measures the total harmonic distortion (THD) for each phase, i.e. current

THDI and voltage THDU. According to EN50160, a 10-minute mean value for THDU for each phase

is calculated. If one of these values exceed 8 %, which is the maximum limit in EN50160, the event

is registered in an occurrence counter register for the specific phase. The calculation of THD

includes up to the 40th harmonics.

In total, OMNIPOWER® has six occurrences counter registers for THD, three for THDU and three

for THDI (one for each phase). All six registers are logged in the occurrence counter logger.

Both THDU and THDI is also available in the analysis logger for continuously logging of the mean

value according to the integration period for the analysis logger.

4.13.8 Readout of the power quality measurements

As described in the previous sections, OMNIPOWER® continuously makes a number of power

quality measurements. The result of the measurements is registered in two loggers:

1. A voltage quality logger : Logs overvoltage, undervoltage and voltage outage events.

2. An occurrence counter logger : Logs the number of events of different power qualityparameters.

In the following sections, some examples are given of the information that the two loggers provide

when they are readout from the meter.

4.13.8.1 Voltage quality logger (1.1.99.98.16.255)

The figure below shows how the mean voltage is calculated in terms of a 10-seconds sample

period. Normally, the sample period will be longer, e.g. 1 minute or 10 minutes. The corresponding

value for the actual consumed power, measured as a mean value in the same period as the

voltage event, is also logged.

66

68


Example of long-term voltage deviations

For the example above, the corresponding information in the logger is shown in the table below.

For every period the mean value is outside the limits, there is a log entry.

Log

ID

Time Phase Event Mean value Max value Min Value Actual Power

1 13:50:10

(Start time)

1 (L1) 0

(Undervoltage)

215 V 230 V 204 V 10.80 kW

2 13:50:30

(Start time)

1 (L1) 1

(Overvoltage)

244 V 260 V 220 V 3.39 kW

Examples of a registration of long time voltage deviations in the voltage quality logger

Examples of a registration of long time voltage deviations in the voltage quality logger

Similarly, you can see a different short-term voltage deviations in the figure below.

Example of short-term voltage deviations


For the example above, the corresponding information in the readout is shown in the table below.

For every period where several values are outside the limits, the first value, the

minimum/maximum value and the last value is registered.

Log

ID

Time Phase Event Mean

value

Max

value

Min Value Actual

Power

3 14:32:17 1 (L1) 6 (Single value min start) 0 V 0 V 210 V 9.87 kW

4 14:32:19 1 (L1) 2 (Single value min peak) 0 V 0 V 204 V 10.25 kW

5 14:32:20 1 (L1) 7 (Single value min stop) 0 V 0 V 208 V 10.10 kW

6 14:32:27 1 (L1) 6 (Single value min start) 0 V 0 V 204 V 12.41 kW

7 14:32:34 1 (L1) 8 (Single value max start) 0 V 253 V 0 V 4.78 kW

8 14:32:39 1 (L1) 3 (Single value max peak) 0 V 262 V 0 V 2.67 kW

9 14:32:40 1 (L1) 9 (Single value max stop) 0 V 252 V 0 V 2.44 kW

Examples of a registration of short time voltage deviations in the voltage quality logger

4.13.8.2 Occurrence counter logger (1.1.99.98.17.255)

A large number of occurrence counter registers are described in the previous sections. In the table

below, these registers are all listed in an example of a readout of the occurrence counter logger

with a log interval of one day. That is, every midnight, the numbers in the occurrence counter

registers are logged.

With this information, it is possible to calculate the total percentage of time that conditions have

been outside the limits given in EN 50160. The table shows these calculations to the right. In the

example, it can be seen that the THDU_L2 is above the requirements (THDI higher than 8% for

more than 5 % of the time in a week).

Log ID (Daily) 1 2 3 4 5 6 7 No. of

events in

a week

Total

time in a

week

RTC (example with daily log interval) 22/01 23/01 24/01 25/01 26/01 27/01 28/01

VQ_Counter_F1 (50Hz – 2%) 0 0 0 0 0 0 0 0 0

VQ_Counter_F2 (50Hz + 2%) 0 0 0 0 0 0 0 0 0

VQ_Counter_VoltageVariation_Low1

(<10% of Un for a 10-minute mean value)

2 3 5 2 9 6 4 31 3.1 %

VQ_Counter_VoltageVariation_Low2

(<15% of Un for a 10-minute mean

value)

0 0 0 0 1 0 1 2 0.2 %


Log ID (Daily) 1 2 3 4 5 6 7 No. of

events in

a week

Total

time in a

week

VQ_Counter_VoltageVariation_High

(>10% of Un for a 10-minute mean

value)

1 1 2 1 1 2 1 9 0.9 %

VQ_Counter_RapidVoltageChanges 3 4 4 5 1 2 2 21

VQ_Counter_Voltage_Unbalance 1 1 2 7 2 1 1 15 1.5 %

VQ_Counter_Interupts_Long 0 0 0 0 0 0 0 0

VQ_Counter_Interupts_Short 0 0 0 1 2 0 0 3

VQ_Counter_THD_U_L1 2 3 1 2 3 2 2 15 1.5 %

VQ_Counter_THD_U_L2 9 8 12 8 14 7 10 68 6.7 %

VQ_Counter_THD_U_L3 1 1 4 3 1 2 1 13 1.3 %

VQ_Counter_THD_I_L1 4 2 1 2 1 1 2 13 1.3 %

VQ_Counter_THD_I_L2 2 1 2 2 3 4 1 15 1.5 %

VQ_Counter_THD_I_L3 1 2 3 1 2 2 1 12 1.2 %

VQ_Counter_Sags 6 7 4 1 5 7 3 33

VQ_Counter_Swells 0 1 2 1 1 0 2 7

An example of readout of the occurrence counter logger

The interval of logging can be configured to daily, weekly or monthly.

4.13.9 Power factor

OMNIPOWER® also measures the power factor for each phase. The values are available for

display readout and the instantaneously values can also be read on request. It is also possible to

add power factor measurement in the analysis logger.

4.13.10 Neutral fault detection

OMNIPOWER® can detect whether the neutral connection (N) on the supply side is disconnected.

This is also called neutral fault. The purpose of the neutral fault detection is to register if the

attached electronic equipment could be exposed to overvoltage which can damage the equipment

and/or cause injury. Neutral fault detection only applies to the three-phase, four-wire meter type.

The figures below illustrate how OMNIPOWER® detects neutral faults related to the supply side,

but not on the demand (or consumer) side.


Neutral fault detection for three-phase meters and CT meters

The neutral fault detection functionality is based on voltage measurements and voltage thresholds,

which is described in the following.

The figures below show a situation without neutral fault and one with neutral fault.

Neutral fault measurement principle


When the neutral fault is present, the load is asymmetric, and the neutral fault voltage VN occurs.

The green vectors indicate the phase voltages on the grid. The yellow vectors indicate the phase

voltages measured by the meter.

The neutral fault is detected when the following three conditions are present:

1. Two of the phase voltages VL1, VL2 and VL3 are above the threshold voltage VLhiTh. The

default value is 253 V.

2. One of the phase voltages VL1, VL2 and VL3 is below the threshold voltage VLloTh. VLloTh is

equal to 230V – VNTh, where – VNTh is set to 40, i.e. VLloTh = 190 V.

3. Condition 1 and 2 must be present in a time period longer than the time period called “neutralfault time”. The default value is 60 seconds.

Under some conditions, a neutral fault is not detected. In a situation with symmetric load, the

neutral fault voltage VN will theoretically be zero volts and neutral fault will not be detected, even if

the neutral is missing.

In the figure below, a neutral fault is not detected in the white areas.

Neutral fault detection range

In the figure to the left, the yellow areas indicate when the neutral fault will be detected. In the figure

to the right, a situation is shown where the neutral fault is detected since the conditions are as

follows:

· VL1 < VLloTh

· VL2 > VLhiTh

· VL3 > VLhiTh

The parameters VNTh, VLhiTh and the neutral fault time can be configured with the registers

(shown with default values):

OBIS code Parameter Description Default value

1.1.134.0.9.255 NeutralFaultVNThreshold The threshold for neutral voltage in neutral

fault detection.

40 VAC


OBIS code Parameter Description Default value

1.1.134.0.10.255 NeutralFaultVLThreshold The threshold for line voltage in neutral fault

detection.

253 VAC

1.1.134.0.11.255 NeutralFaultTime The time for neutral fault to be detected

before the event.

60 sec.

4.13.10.1 Neutral fault logger (1.1.99.98.12.255)

OMNIPOWER® has a logger for neutral fault events where every event is registered with a time

stamp. The neutral fault event logger has a depth of 45 log entries.

In a smart metering system, it is possible for the meter, in case of a neutral fault, to send a push

alarm to the meter data management (MDM) system and in this way warn the utility of the situation

as quickly as possible.

In meters with integrated breakers, there is also the possibility to disconnect the breaker in the

meter in case of neutral fault detection.

4.13.11 Earth fault detection

For three-phase, three-wire meters (Aron) and some specific single-phase meters, which are

installed in IT- and TT-distribution network, it is possible to activate an integrated earth fault

detection functionality.

Earth fault detection is based on current summation of the three phase currents. The sum of

currents for all phases is called IIearth as shown in the figure below.

Earth fault current

The meter samples the value of this current in the sample period called tearth_average. If the

sampled value, called Iearth_average is above the threshold, Ithreshold, the meter detects the

event as an earth fault. Each event is identified with a start, a peak and a stop, as shown in the

figure below.


Earth fault detection by the meter

The values of tearth_average and Ithreshold are configurable in the range from 1-3600 sec. and 1-

2000 mA, respectively. Changing the configuration values will change the behaviour of earth fault

detection as shown in the figure below.

Configurable parameters for earth fault detection will change the behaviour of the function

4.13.11.1 Earth fault detction logger (1.1.99.98.19.255)

The OMNIPOWER® meters mentioned in the previous section have a logger for earth fault

detection, which can be activated and deactivated as required.

When the logger is activated, the meter will register the event where Iearth_average > Ithreshold

the event in the earth fault detection logger (Start). The event is registered with a time stamp and

an actual value of Iearth_average.

The meter will also make a registration when Iearth_average < Ithreshold (Stop). At the same time,

the meter also makes a registration of the maximum value of Iearth_average, which is measured

during the period between the start and the stop time for the earth fault (peak).


4.14 Other smart grid functionalities

OMNIPOWER® is developed to meet the future smart grid requirements. This is underlined by the

power quality measurements, but also by a number of additional functionalities, such as meter

firmware upload, integration of push alarms, and control of in-home relays and the implementation

of Multi-Utility Controller in the meter.

The functions are described in the following sections.

4.14.1 Firmware upload

It is possible to upload new meter firmware remotely with OMNIA®. This functionality is developed

according to the WELMEC Software guide 7.2 and is approved in accordance with the MID type

approval of the meter.

For further information regarding the firmware upload functionality, please contact Kamstrup A/S.

4.14.2 Alarm handling/push alarms

OMNIPOWER® can be configured to give an alarm when specific events are registered by themeter. As the alarm is pushed from the meter, the term “push alarm” is used.

The following events can be configured to generate push alarms:

· Magnetic detection

· Tamper detection

· Internal meter error

· Undervoltage and overvoltage detection

· Missing phase voltage detection

· Neutral fault detection

· Earth fault detection

· Disconnection and manual reconnection of breakers

The alarms are transmitted through the OMNICON® communication network or to the module port.

For further details about alarms and alarm configurations, please contact Kamstrup A/S.

4.14.3 All phase power outage alarm ("last gasp")

In addition to the previous section, OMNIPOWER® Variant 2 introduces an alarm notification called

“last gasp” in case of a total power outage, i.e. a power outage on all phases on the grid side of the

meter.

If an all phase power outage occurs, the affected OMNIPOWER® meters with internal radio will

broadcast a “last gasp” alarm, which is relayed through the radio network to the OMNIA® System.

Note A meter which is affected itself by the power outage will not be able to repeat “last gasp”

alarms from nearby located meters.


4.14.4 Control of external load relays

As an option, it is possible to install a two-relay load control module in the meter. The load control

relays can be used to control the consumer’s installation. The control of the relays on the module

can be done in two ways:

· By predefined (configurable) load control plans managed by the meter.

The plan can be set independently for each meter and can also be set to follow a specific tariffplan. Load control plans can be remotely updated from OMNISOFT® VisionAir.

Note Due to any preprogrammed delay in the meter on the relay-shift, it is important torestart the meter (on/off) when the time is set correctly in the meter. This place therelays in the correct position and stops the delay timer.

· By remote on-demand commands sent from a smart metering system.

For more details about how the load control relay is configured, please see “Load control

configuration ”.

4.14.5 Multi-utility options

It is possible to install a Multi-Utility Controller (MUC) module in OMNIPOWER®. With this module,

consumption data from nearby flow meters as heat, water or gas meters can be read out.

Afterwards, the data can be sent to OMNISOFT® VisionAir using the OMNICON® network. The

setup is shown below.

98


Multi-Utility Controller in OMNIPOWER®

For more information about the Multi-Utility Controller module and the flow meter data which can be

accessed, please contact Kamstrup A/S.

4.14.6 Miscellaneous use

As default, OMNIPOWER® has an S0 pulse output (described in “S0 output ”) and two available

I/O (input/output) ports on the module interface. The use of one or both I/O ports in the module

area requires that the meter is equipped with a module that supports the wanted functionality.

4.14.7 Pulse inputs in the module area

The pulse inputs in the module area (module I/O) can be configured with the following

functionalities:

· Tariff control, see also the table "Tariff control table "

· Pulse input from other units

· Alarm input for the registration of an external alarm

78

34


The pulse input accumulates pulses in the pulse input register. If this register is shown in the

display, it is updated every 10 seconds. It is possible to scale the reading of the pulse input by a

”pulse factor” in the range from 0.1 to 1000 units per pulse.

The maximum permissible frequency for input pulses is 25 Hz.

In relation to the pulse input register, the unit for the register can be set to the following:

· kWh

· m3

· l

· “None”

4.14.7.1 Example of pulse input from a water meter

A water meter emits 1 pulse per 25 l. The required reading in the electricity meter’s display is m3

without decimals.

1000 l = 1 m3, 1000 / 25 = 40 > pulse division factor to be set to 40.

The electricity meter count will be incremented by one at every 40 pulses, i.e. indication in m3

without decimals. The most frequently used pulse values appear from the table below.

Pulse value

l/Imp

Pulse value

Imp/m3

Pulse division factor

Display indication in ”m3

”


Display indication in ”l”

100 10 10 -

50 20 20 -

25 40 40 -

10 100 100 0.1

5.0 200 200 5

2.5 400 400 2.5

1.0 1000 1000 1

1000 1 1 1000

Pulse values for water meters

4.14.7.2 Example of pulse input from an electricity meter

The table below shows a similar list of pulse values for electricity meters.

Pulse value

Wh/imp

Pulse value

Imp/kWh


Display indication in kWh

100000 0.01 -

10000 0.1 0.1

1000 1 1

16.67 60 60


Pulse value

Wh/imp

Pulse value

Imp/kWh


Display indication in kWh

13.33 75 75

8.333 120 120

4.167 240 240

2.941 340 340

2.083 480 480

1.667 600 600

1.000 1000 1000

0.100 10000 -

Pulse values for electricity meters

4.14.8 Pulse outputs in module area

The pulse outputs in the module area can be configured for pulse outputs for both active and

reactive energy.

By default, the pulse outputs send 1 pulses/kWh. It can, however, be configured between 1 – 1000

pulse/kWh. In addition, the pulse width can be configured for 30 or 80 msecs.

Note When selecting pulse/kWh-factor and pulse width, be aware that the number of pulses at

maximum load do not exceed the number which the meter is able to send via the pulse

output.

Pulse value

Imp/kWh, Imp/kvar

Pulse duration/

pulse pause

30 msecs. 80 msecs.

1 100A 100A

10 100A 100A

100 100A 100A

1000 86A 32A

Maximum load current at different pulse/kWh values

4.14.9 S0 output

The S0 output provides pulses/kWh permanently. The pulses are synchronized with the S0 LED.

For number of pulses/kWh, please see "Electrical specifications" .

The S0 output is specified according to the DIN 43864 standard. The figures below show the

placement of the S0 output connector.

The maximum voltage that can be connected to the S0 output is 27 V DC (at 1 kW), and the

maximum current through the output is 27 mA.

11


The S0 output on a three-phase and a CT meter

The S0-LED will in normal operation always flash according to the consumption, i.e. A+. However,

it can change if the meter switches to verification mode. Then it will follow the activated quadrant.

The table below lists the technical specification for the S0 output.

The status of the

pulse sensor

Test conditions Test data

Supply voltage

UB

Internal resistance

RV

Current through the

S0 output

On (active) 18 V DC 1 kΩ i > 10 mA

Off (inactive) 27 V DC 1 kΩ i < 2 mA

S0 technical specification

On the three-phase direct meter with auxilliary power supply (APS), the S0 output is not available.

The S0 output can then only be achieved as a module interface.

4.14.10 Auxiliary power supply (APS)

As an option, the three-phase direct meter can be configured with auxiliary power supply (APS)

functionality. This allows to supply the meter with 230VAC on a separate input as shown in the

figure below.

The functionality is useful when an external breaker is installed before the meter in an installation.


APS functionality

Important It is important that the APS is connected to phase L3.

Note When the meter is configured for APS, it does not have an S0 output as the connector is

used for the 230 V APS.


5 Ordering specification______________________________________________________________This chapter contains order information on all aspects of OMNIPOWER®, including hardware,

software and all other relevant configurations such as customer label, sealing, packaging, etc.

5.1 Meter configuration

The configuration of OMNIPOWER® is divided into two main parts:

· Hardware configuration

Specifies the meter regarding number of phases, current specification, internal breaker,integrated radio, etc. It also defines the meter type number which is printed on the meter front.

· Software configuration

Specifies the configurable setup and meter variables including display setup, smart disconnectsettings, tariff and load control plans, voltage quality parameters, etc.

A number of related extended software configuration options are available:

· Display setup

· Tariff setup

· Load control setup

· Smart disconnect

· Sealable push button setup

· Analysis logger setup

· 1107 setup

Each of them has a related separate order form. The different order forms are shown in the

following sections.

5.2 Hardware configuration

X1 X2 X3 X4 X5 X6 X7 X8 X9 X10 X11 X12 X13 X14-X16

68

X1 – Meter type

OMNIPOWER® single-phase

6

OMNIPOWER® CT 5


4

X2 – Type no. version

OMNIPOWER® 1



X3 – Housing

Standard 1

ST-meter (BS7856)Single-phase

2

DIN rail meter 4

X4 – Measuring

systems

1 system 1

2 systems (Aron) 2

3 systems 3

X5 – Current range

Directmeters

CT meters

5(100)A 1(6)A 1

5(65)A 4

5(6)A 5

10(60)A 6

10(80)A 7

5(80)A 8

5(63)A 9

X6 – Accuracy class

Directmeters

CT meters

Class A A

Class B Class B B

Class C C

Class 2 2

Class 1 Class 1 1

Class 0,5 5

X7 – Generation

Generation D** D

Generation N*** N

X8 – Variant

1st Variant 1

2nd variant* 2

X9 – Energy type

A+ 1

A+/A- 2

A+/R+** 3

A+/A-/R+/R 4

X10 – Breaker



No breaker 0

Dual breaker*** (single-phase only)

2

Standard breaker*** 3

DIN rail breaker 4

X11 – Communication

No radio 0

Radio (For OMNIA®) 1

X12 – Supply back-up

Supercap*** 0

Supercap + battery 1

X13 – Interface

S0 output 1

APS*** 2

X14X15X16 – Country

code

Denmark 010

Denmark 011

Denmark 012

Russia 025

Spain 031

Turkey 035

Croatia 036

Serbia 037

Norway 040

Slovakia 042

Czech Republic 043

Hungary 044

Latvia 045

Lithuania 049

United Kingdom 050

Austria 055

Austria 056

Switzerland (Italian part) 059

Estonia 061

Switzerland (Germanpart)

063

Poland 064

Switzerland (French part) 065

Iceland 067

Germany 070

Belgium 078

The Netherlands 080

Finland 084

Finland (Aland island) 086



Sweden 090

Saudi Arabia 110

South Africa 120

Ghana 121

Chile 151

* Does not support 1107 communication protocol.

** OMNIPOWER® CT meters only.

*** OMNIPOWER® direct meters only.

5.3 Software configuration

Z1 Z2 Z3 Z4

Z1 – Decimals in display

Direct meters CT meters

7.0 7.0 1

6.1 7.1 2

7.2 7.2 3

6.3 NA 4

Z2 – LED configuration

LED off at no consumption 1

LED on at no consumption 2

Z3 – Primary module configuration I/O 1 I/O 2

No function _ _ 00

4-tariff Input Input 01

4-tariff inverted Input Input 02

Pulse in / Alarm in Input Input 03

Pulse in / Alarm in inverted Input Input 04

Pulse in / A+ out Input Output 05

R+ out / A+ out Output Output 06

2-tariff / Alarm in Input Input 07

2-tariff inverted / Alarm in Input Input 08

2-tariff / Alarm in inverted Input Input 09

2-tariff inverted / Alarm in inverted Input Input 10

2-tariff / A+ out Input Output 11

2-tariff inverted / A+ out Input Output 12

Pulse in / 2-tariff Input Input 13

Pulse in / 2-tariff inverted Input Input 14

Debiting stop pulse / - Input _ 15

A- out / A+ out Output Output 16

Load control load / Status control Input Output 17

Pulse in / Load tariff sync Input Output 18

Pulse in inv. / Load tariff sync Input Output 19

Pulse in / Load tariff sync inverted Input Output 20

Pulse in inv. / Load tariff sync inverted Input Output 21


Z1 Z2 Z3 Z4

4-tariff sync load control Input Input 22

4-tariff sync load control inverted Input Input 23

Load control 1 / Load control 2 Output Output 26

Pulse in / Load control Input Output 27

Pulse in / Toggle Load control 1 & 2 Input Output 28

Earth fault I2C I2C 29

Z4 - Integration period / load profile period

15 min. 2

30 min. 3

60 min. 4

Z5 Z6 Z7 Z8

Z5 - Display configuration

See the display order form or contact Kamstrup A/S

Z6 - Debiting stop date

1 012 023 034 045 0523 2324 2425 2526 2627 2728 28Z7 - Debiting logging interval

None (externally controlled) 00Monthly 01Every second month, January 02Every second month, February 03Every third month, January 04Every third month, February 05Every third month, March 06Every six month, January 07Every six month, February 08Every six month, March 09Every six month, April 10Every six month, May 11Every six month, June 12Yearly, January 13Yearly, February 14Yearly, March 15


Z5 Z6 Z7 Z8

Yearly, April 16Yearly, May 17Yearly, June 18Yearly, July 19Yearly, August 20Yearly, September 21Yearly, October 22Yearly, November 23Yearly, December 24Z8 - Pulse out length / alarm input

30 ms pulse length / alarm input deactivated 130 ms pulse length / alarm input active 280 ms pulse length / alarm input deactivated 380 ms pulse length / alarm input active 4

Z9 Z10 Z11 Z12

Z9 - Disconnect setup

See the disconnect order form or contact Kamstrup A/S No disconnect setup 000Default setup 001Z10 - Analysis logger setup

See the analysis logger order form or contact Kamstrup A/SDefault setup 000Z11 - GMT

0 London time 001 + 1 Hour (DK/NO/SE/DE/FR/ES) 012 + 2 Hours ( FI) 023 + 3 Hours 034 + 4 Hours 045 + 5 Hours 056 + 6 Hours 067 + 7 Hours 078 + 8 Hours 089 + 9 Hours 0910 + 10 Hours 1011 + 11 Hours 1112 + 12 Hours 12-11 - 11 Hours 13-10 - 10 Hours 14-9 - 9 Hours 15-8 - 8 Hours 16-7 - 7 Hours 17-6 - 6 Hours 18-5 - 5 Hours 19


Z9 Z10 Z11 Z12

-4 - 4 Hours 20-3 - 3 Hours 21-2 - 2 Hours 22-1 - 1 Hours 23Z12 - Unit pulse input

None 00kWh 01m3 02L 03

Z13 Z14 Z15 Z16 Z17 Z18 Z19 Z20

Z13 - Tariff control plan

See the tariff order form or contactKamstrup A/STariff disabled 000Module port Control (used for 230VAC input tariff control)

001

Register control 002Customized tariff control table xxxZ14 – Load control plan

See the load control order form or contactKamstrup A/SLoad control disabled 000Register control 001Customized load control table xxxZ15 - Daylight saving time /

summer/winter time table

None 000EU 001Z16 - Frequency code protocol

None (only for meters without radio) 000CH 318 RF 318EU 319 RF 319SE 326 RF 326SE 328 RF 328SE 329 RF 329NO 338 RF 338NO 339 RF 339DK 348 RF 348DK 349 RF 349FI 359 RF 359PL 369 RF 369AT 379 RF 379


Z13 Z14 Z15 Z16 Z17 Z18 Z19 Z20

Z17 – Push button 2 setup

See the PB2 order form or contactKamstrup A/SNo PB2 setup 000Z18 - 1107 configuration (only for FW

5098-736 and 50981040)

See the 1107 order form or contactKamstrup A/SDisabled 000Mode A and C, UD1 001Mode A and C, UD2 002Z19 - Breaker position

Undefined (only for meters withoutbreakers)

0

Connected 1Disconnected 2Z20 – Calendar Setup

See Calendar setup order form or contactKamstrup A/SNo exception days 000Customized exception day setup xxx

Z21 Z22 Z23 Z24 Z25

Z21 Transformer ratio14

5A / 5A 1A / 1A 00110A / 5A 2A / 1A 00215A / 5A 3A / 1A 00320A / 5A 4A / 1A 00450A / 5A 10A / 1A 01075A / 5A 15A / 1A 015100A / 5A 20A / 1A 020120A / 5A 24A / 1A 024150A / 5A 30A / 1A 030160A / 5A 32A / 1A 032200A / 5A 40A / 1A 040300A / 5A 60A / 1A 060500A / 5A 100A / 1A 1001000A / 5A 200A / 1A 2001500A / 5A 300A / 1A 3002000A / 5A 400A / 1A 4003000A / 5A 600A / 1A 600Z22 Transformer ratio (unlocked / locked)**

Unlocked 1


Z21 Z22 Z23 Z24 Z25

Locked 2Z23 Load profile, based on**

Primary energy 1Secondary energy 2Z24 Pulse output (module)**

Based on secondary energy 0Based on primary energy 1Z25 Debiting 2 interval

Daily 1Weekly 2Monthly 3** OMNIPOWER® CT meter only.

Z26 Z27 Z28 Z29 Z30

Z26 Alarm Configuration

No alarms enabled 000

Customized alarm configuration xxxZ27 Load Profile Data (DLMS)

Absolute values 1Delta values 2Z28 Local Interface Encryption

Enabled 1Disabled 2Partly enabled 3Z29 Load Profile Configuration

A+ 1A+/A- 2A+/A-/R+/R- 3A+/A-/R1/R2/R3/R4 4A+/A-/R+/R-/R1/R2/R3/R4 5P+/P-/Q+/Q- 6Z30 Debit2 Logger Configuration

Profile 01 – Default 4Q 1Profile 04 – Default 2Q (A+/A-) 4Profile 05 – Default 2Q (A+/R+) 5Profile 06 – Default 1Q 6

Z31 Z32 Z33 Z34

Z32 Analysis Logger Configuration

Profile 01 – Default 4Q 01


Z31 Z32 Z33 Z34

Profile 01 – Default 2Q (A+/A-) 02Profile 01 – Default 2Q (A+/R+) 03Profile 01 – Default 1Q 04Z32 Analysis Logger Configuration

Profile 01 – Default 3P-4Q 01Profile 02 – Default 1P-4Q 02Profile 03 – Default 3P-2Q (A+/A-) 03Profile 04 – Default 1P-2Q (A+/A-) 04Profile 05 – Default 3P-2Q (A+/R+) 05Profile 06 – Default 1P-2Q (A+/R+) 06Profile 07 – Default 3P-1Q 07Profile 08 – Default 1P-1Q 08Z33 Daily Logger Configuration

Profile 01 – Default 01Z34 Energy Format

Energy registers with 2 decimals 2Energy registers with 3 decimals 3

5.4 Display configuration

The possible display readings depend on the chosen energy. In addition, it must be considered

whether leading zeroes should be indicated in the energy display, and whether OBIS codes and

actual quadrant indication are required. Display readings are shown with OBIS codes.

Description OBIS Auto

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Utility

Active positive energy A+ 1.8.0

Active negative energy A- 2.8.0

Reactive positive energy R+ 3.8.0

Reactive negative energy R- 4.8.0

A+, A- active energy numerical

(A1423)

_ 15.8.0 _

Nett active energy(|A+| - |A-|) NET 16.8.0

Reactive energy R1 R1 5.8.0

Reactive energy R2 R2 6.8.0 _ _ _ _

Reactive energy R3 R3 7.8.0 _ _ _ _

Reactive energy R4 R4 8.8.0



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Apparent positive energy E+ 9.8.0

Apparent negative energy E- 10.8.0

Active positive energy, T1 A+/T1 1.8.1 _








Active negative energy, T1 A-/T1 2.8.1 _








Reactive positive energy, T1 R+/T1 3.8.1 _









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Reactive negative energy, T1 R-/T1 4.8.1 _








Resettable counter, Active positive

energy

A+/TRIP 1.128.0 _

Resettable counter, Active negative

energy

A-/TRIP 2.128.0 _

Resettable counter, Reactive positive

energy

R+/TRIP 3.128.0 _

Resettable counter, Reactive

negative energy

R-/TRIP 4.128.0 _

Resettable counter, Apparent positive

energy

E+/TRIP 9.128.0 _

Resettable counter, Apparent

negative energy

E-/TRIP 10.128.0 _

Active positive energy phase L1 A+/L1 21.8.0 _



Active negative energy phase L1 A-/L1 22.8.0 _



Actual active positive power P+ 1.7.0 _

Actual active negative power P- 2.7.0 _

Actual reactive positive power Q+ 3.7.0 _



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Utility

Actual reactive negative power Q- 4.7.0 _

Apparent positive power S+ 9.7.0 _

Apparent negative power S- 10.7.0 _

Active positive max power P+M 1.6.0 _

Time stamp active positive max

power

TIME/DAT

E

1.6.0 _

Active negative max power P-M 2.6.0 _

Reactive positive max power Q+M 3.6.0 _

Time stamp reactive positive max

power

TIME/DAT

E

3.6.0 _

Reactive negative max power Q-M 4.6.0 _

Active positive max power tariff 1 P+M/T1 1.6.1 _


power tariff 1

TIME/DAT

E

1.6.1 _

Active positive max power tariff 2 P+M/T2 1.6.2 _


power tariff 2

TIME/DAT

E

1.6.2 _

Reactive positive max power, T1 Q+M/T1 3.6.1 _


power, T1

TIME/DAT

E

3.6.1 _

Reactive positive max power, T2 Q+M/T2 3.6.2 _


power, T2

TIME/DAT

E

3.6.2 _

Accumulated active positive max

power

P+M/ACC 1.2.0 _

Accumulated active negative max

power

P-M/ACC 2.2.0 _

Accumulated reactive positive max

power

Q+M/ACC 3.2.0 _

Accumulated reactive negative max

power

Q-M/ACC 4.2.0 _


power tariff 1

P+M1/ACC1.2.1 _


power tariff 2

P+M2/ACC1.2.2 _



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Pulse input _ 0.128.1 _

Display test _ _ _

Meter number 1 NUM/1 0.0.1 _



Meter serial number SER/NUM 96.1.0 _

Special data 1 SPC/1 0.130.1 _

Actual voltage phase L1 U-L1 32.7.0 _



Actual current phase L1 I-L1 31.7.0 _



Date and Time TIME/DAT

E

1.0.0 _

Number of debiting periods RST 0.1.0 _

Actual positive power phase L1 P+/L1 21.7.0 _



Historical data _ 98.1.0 _ _

Load profile data _ 99.1.0 _ _

Power threshold value PTH 96.51.1 _

Power threshold counter PTH/CNT 95.51.2 _

Hour counter HRS 96.8.0 _

Call CALL _ _ _

ROM checksum CSUM 96.54.1 _



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Software number _ 0.2.0 _

Meter status INFO 97.97.0 _

Active positive max. power per day MAX 1.16.0 _

RTC active positive max. power per

day

TIME/DAT

E

1.16.0 _

Active positive min. power per day MIN 1.13.0 _

RTC active positive min. power per

day

TIME/DAT

E

1.13.0 _

Load profile event status _ _ _

Power factor L1 PF-1 33.7.0 _



Power factor Total PF 13.7.0 _

Frequency FREQ 14.7.0 _

Total harmonic distortion, Voltage L1 THD/U-L1 32.7.124 _



List of available display readings from the order form "Display configuration OMNIPOWER®" (doc.5811-2371)

For direct meters only


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Manual disconnect _ _ _ _

Active positive energy

Prepayment

_ 130.0.0 _

Active positive energy

Prepayment - credit

_ 130.0.1 _

Total harmonic distortion, Current

L1

THD/I-L1 31.7.124 _


L2

THD/I-L2 51.7.124 _



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Utility


L3

THD/I-L3 71.7.124 _

List of available display readings from the order form "Display configurationOMNIPOWER®" (doc.5811-2371)

For CT meters only


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Utility

Transformer ratio CTR 0.4.2 _

Secondary active positive energy A+ S 1.8.0

Secondary active negative

energy

A- S 2.8.0

Secondary reactive positive

energy

R+ S 3.8.0

Secondary reactive negative

energy

R- S 4.8.0

Secondary reactive energy R1 R1 S 5.8.0

Secondary reactive energy R4 R4 S 8.8.0

Secondary active positive energy,

T1

A+ S/T1 1.8.1 _


T2

A+ S/T2 1.8.2 _


T3

A+ S/T3 1.8.3 _


T4

A+ S/T4 1.8.4 _


T5

A+ S/T5 1.8.5 _


T6

A+ S/T6 1.8.6 _


T7

A+ S/T7 1.8.7 _


T8

A+ S/T8 1.8.8 _


energy, T1

A- S/T1 2.8.1 _



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energy, T2

A- S/T2 2.8.2 _


energy, T3

A- S/T3 2.8.3 _


energy, T4

A- S/T4 2.8.4 _


energy, T5

A- S/T5 2.8.5 _


energy, T6

A- S/T6 2.8.6 _


energy, T7

A- S/T7 2.8.7 _


energy, T8

A- S/T8 2.8.8 _


energy, T1

R+ S/T1 3.8.1 _


energy, T2

R+ S/T2 3.8.2 _


energy, T3

R+ S/T3 3.8.3 _


energy, T4

R+ S/T4 3.8.4 _


energy, T5

R+ S/T5 3.8.5 _


energy, T6

R+ S/T6 3.8.6 _


energy, T7

R+ S/T7 3.8.7 _


energy, T8

R+ S/T8 3.8.8 _


energy, T1

R- S/T1 4.8.1 _


energy, T2

R- S/T2 4.8.2 _


energy, T3

R- S/T3 4.8.3 _


energy, T4

R- S/T4 4.8.4 _



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energy, T5

R- S/T5 4.8.5 _


energy, T6

R- S/T6 4.8.6 _


energy, T7

R- S/T7 4.8.7 _


energy, T8

R- S/T8 4.8.8 _

List of available display readings from the order form "Display configuration OMNIPOWER®" (doc.5811-2371)

5.5 Tariff control configuration

For further information about configuration of tariffs, please contact Kamstrup A/S.

5.6 Load control configuration

For further information about configuration of load control, please contact Kamstrup A/S.

5.7 Smart disconnect setup

For further information about configuration of smart disconnect, please contact Kamstrup A/S.

5.8 Sealable push button configuration

As an option, the meter push buttons have a number of functionalities (as described in "Push

button functionalities ").

The right side positioned push button can be configured regarding which functions are enabled or

not. The configuration must be done when ordering of the meter. The configuration options for right

side positioned sealable push button are listed in the table below.

Description Enable/Disable

PB2 functionality

Subfunctions

Debiting stop

Set date and time

Adjust time

Set optical interface

View manual utility display list Remember to configure the display list

Set meter number

23


Description Enable/Disable

Release permanent tamper This function is for future use and is not available yet

Module installation mode This function is for future use and is not available yet

Manual selection of tariff plan

Manual selection of load control

plan

Test of load control plan

List of available functions attached to the sealable push button

This list is part of the OMNIPOWER® meter configuration order form.

5.9 1107 protocol configuration

For further information about configuration of the 1107 protocol, please contact Kamstrup A/S.

5.10 Customer labels

The label consists of two parts:

· a meter label describing the choices made under type number.

· a customer label created on basis of the customer's wishes.

Note The customer label must be approved by the customer before an order can be createdto the customer.

Both label parts are engraved with laser on front of the meter.

Four standard customer labels without customer logo are available:

2019000 No bar code No meter number

2019001 Code 128 Meter number = serial number

2019002 2 of 5 interleaved Meter number = serial number

2019003 Code 39 Meter number = serial number

The following information is required for the creation of a new customer label:

· The customer logo must be provided to the Electricity Product Group at Kamstrup A/S. The logomust be in black/white and in one of the following formats: JPG or WMF.

· Information about the bar code type to use and its content, serial number, meter number,installation number, and the position of numbers and bar code must also be provided.

When all information is available, a draft is prepared which must be approved by the customer.

The bar code should also be read by the customer in order to secure that his bar code reading

device can read the bar code.


After approval, a customer label no. 2019XXX is selected, and the number is released in the

Kamstrup ordering systems.

The customer label 2019xxx for OMNIPOWER® three-phase and single-phase meters

The customer label 2019xxx is of the same size on all meter types. This means that the same

customer label can be used both on the single-phase and the three-phase meters.

5.11 Sealing

The meter is/can be sealed on different levels. The verification cover is “lifetime” sealed, i.e. the

cover cannot be unsealed without damaging the cover and the meter. The meter cover can be

sealed by the utility as can the CCC module slot. Finally, the right push button also offers sealing of

its push action. Only authorized personnel is allowed to break the utility sealing.


Sealing options for OMNIPOWER® single-phase and three-phase meter

5.12 Packing

OMNIPOWER® can be delivered in three ways:

· Boxes – 1 meter per box

· Boxes – 4 meters per box

· Pallets – 160 three-phase meters or 250 single-phase meters on a pallet.


5.12.1 Box solution

The meters are packed in boxes with either 1 or 4 in each box. 4-piece boxes are placed on pallets

with 40 boxes on each pallet as shown below.

5.12.2 Pallet solution


5.13 Accessories

SOFTWARE TOOL

METERTOOL OMNIPOWER® (configuration software) 68 99 570

VARIOUSThree-phase covers

Standard meter cover (for three-phase meters) 59 60 315

Long meter cover, 60 mm (for three-phase meters) 59 60 316

Extra long meter cover, 100 mm (for three-phase meters) 59 60 317

Single-phase covers

Standard meter cover (for single-phase meters) 59 60 322

Long meter cover, 60 mm (for single-phase meters) 59 60 323

Extra long meter cover, 100 mm (for single-phase meters) 59 60 xxx

(not availab le yet)

Single-phase covers for ST-meter

Standard meter cover (for single-phase meters) 59 60 617

Long meter cover, 60 mm (for single-phase meters) 59 60 323


Optical reading head with USB connector 66 99 099

Optical reading head with 9-pole D-sub connector 66 99 102

METERTOOL OMNIPOWER® kit (RS232 module with USB connector) 68 30 017

Pins, 50 pcs. 68 50 102

Cable sockets, 50 pcs. 68 50 103

Date post:	25-May-2021
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